rules for construction of power boilers -...

2010 ASME Boiler and Pressure Vessel CodeA N I N T E R N A T I O N A L C O D E

I Rules for Construction of Power Boilers

Copyright ASME International Provided by IHS under license with ASME Licensee=Korea Power Engineering Co Inc ( KOPEC ) /3289500001

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A N I N T E R N A T I O N A L C O D E

2010 ASME Boiler &Pressure Vessel Code2010 Edition July 1, 2010

IRULES FOR CONSTRUCTIONOF POWER BOILERSASME Boiler and Pressure Vessel Committee on Power Boilers

Three Park Avenue • New York, NY • 10016 USA



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Date of Issuance: July 1, 2010(Includes all Addenda dated July 2009 and earlier)

This international code or standard was developed under procedures accredited as meeting the criteria for American NationalStandards and it is an American National Standard. The Standards Committee that approved the code or standard was balancedto assure that individuals from competent and concerned interests have had an opportunity to participate. The proposed codeor standard was made available for public review and comment that provides an opportunity for additional public input fromindustry, academia, regulatory agencies, and the public-at-large.

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The footnotes in this document are part of this American National Standard.

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Library of Congress Catalog Card Number: 56-3934Printed in the United States of America

Adopted by the Council of the American Society of Mechanical Engineers, 1914.Revised 1940, 1941, 1943, 1946, 1949, 1952, 1953, 1956, 1959, 1962, 1965, 1968, 1971, 1974, 1977, 1980, 1983, 1986,

1989, 1992, 1995, 1998, 2001, 2004, 2007, 2010

The American Society of Mechanical EngineersThree Park Avenue, New York, NY 10016-5990

Copyright © 2010 byTHE AMERICAN SOCIETY OF MECHANICAL ENGINEERS

All Rights Reserved



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CONTENTS

List of Sections . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xiiiForeword . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xvStatements of Policy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xviiPersonnel . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xviiiPreamble . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xxxSummary of Changes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xxxiiList of Changes in Record Number Order . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . xxxvii

PART PG GENERAL REQUIREMENTS FOR ALL METHODS OFCONSTRUCTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

General

PG-1 Scope . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1PG-2 Service Limitations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1PG-3 Referenced Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1PG-4 Units. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

Materials

PG-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2PG-6 Plate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3PG-7 Forgings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3PG-8 Castings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3PG-9 Pipes, Tubes, and Pressure-Containing Parts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4PG-10 Material Identified With or Produced to a Specification Not Permitted by

This Section, and Material Not Fully Identified . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6PG-11 Miscellaneous Pressure Parts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8PG-12 Water Level Indicators and Connector Material . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9PG-13 Stays. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9PG-14 Rivets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9

Design

PG-16 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10PG-17 Fabrication by a Combination of Methods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10PG-18 Design Validation by Proof Test . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10PG-19 Cold Forming of Austenitic Materials . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10PG-20 Cold Forming of Creep Strength Enhanced Ferritic Steels . . . . . . . . . . . . . . . . . . . . . 11PG-21 Maximum Allowable Working Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11PG-22 Loadings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11PG-23 Stress Values for Calculation Formulas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11PG-25 Quality Factors for Steel Castings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13PG-26 Weld Joint Strength Reduction Factor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15PG-27 Cylindrical Components Under Internal Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15PG-28 Welded Access or Inspection Openings Under External Pressure . . . . . . . . . . . . . . . 20PG-29 Dished Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20PG-30 Stayed Dished Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22PG-31 Unstayed Flat Heads and Covers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22

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Openings and Compensation

PG-32 Openings in Shells, Headers, and Dished Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26PG-33 Compensation Required for Openings in Shells and Dished Heads . . . . . . . . . . . . . 27PG-34 Flanged-In Openings in Formed Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30PG-35 Compensation Required for Openings in Flat Unstayed Heads and Flat Stayed

Plates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30PG-36 Limits of Metal Available for Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31PG-37 Strength of Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31PG-38 Compensation for Multiple Openings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32PG-39 Methods of Attachment of Pipe and Nozzle Necks to Vessel Walls . . . . . . . . . . . . 32PG-42 General Requirements for Fittings, Flanges, and Valves . . . . . . . . . . . . . . . . . . . . . . . 33PG-43 Nozzle Neck Thickness . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36PG-44 Inspection Openings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36PG-46 Stayed Surfaces . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37PG-47 Staybolts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37PG-48 Location of Staybolts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38PG-49 Dimensions of Staybolts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38PG-52 Ligaments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38PG-53 Ligaments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41PG-55 Supports and Attachment Lugs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41

Boiler External Piping and Boiler Proper Connections

PG-58 Outlets and External Piping . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41PG-59 Application Requirements for the Boiler Proper . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48

Design and Application

PG-60 Requirements for Miscellaneous Pipe, Valves, and Fittings . . . . . . . . . . . . . . . . . . . . 50PG-61 Feedwater Supply . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53

Overpressure Protection Requirements

PG-67 Boiler . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54PG-68 Superheater and Reheater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 57PG-69 Certification of Capacity of Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . 58PG-70 Capacity of Pressure Relief Valves. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 63PG-71 Mounting of Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65PG-72 Operation of Pressure Relief Valves. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67PG-73 Minimum Requirements for Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . 68

Fabrication

PG-75 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72PG-76 Cutting Plates and Other Stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72PG-77 Plate Identification . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72PG-78 Repairs of Defects in Materials . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72PG-79 Tube Holes and Ends . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72PG-80 Permissible Out-of-Roundness of Cylindrical Shells. . . . . . . . . . . . . . . . . . . . . . . . . . . 72PG-81 Tolerance for Formed Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73PG-82 Holes for Stays . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73

Inspection and Tests

PG-90 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74PG-91 Qualification of Inspectors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74PG-93 Inspection and Repair of Flat Plate in Corner Joints . . . . . . . . . . . . . . . . . . . . . . . . . . 75PG-99 Hydrostatic Test. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75

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Certification by Stamping and Data Reports

PG-101 Heating Surface Computation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75PG-104 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76PG-105 Code Symbol Stamps . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76PG-106 Stamping of Boilers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78PG-107 Field Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80PG-108 Stamping for Field-Assembled Boilers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 81PG-109 Stamping of Pressure Piping. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 81PG-110 Stamping of Boiler Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 82PG-111 Location of Stampings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 82PG-112 Manufacturer’s Data Report Forms. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 83PG-113 Master Data Report Form . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 85

FiguresPG-28 Maximum Internal Projection of Welded Access or Inspection Openings. . . . . . . . 20PG-31 Some Acceptable Types of Unstayed Flat Heads and Covers . . . . . . . . . . . . . . . . . . 23PG-33.1 Nomenclature and Formulas for Reinforced Openings. . . . . . . . . . . . . . . . . . . . . . . . . 28PG-33.2 Some Representative Configurations Describing the Dimensions te, h, and d. . . . . 29PG-33.3 Chart for Determining Value of F. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30PG-38 Illustrations of the Rule Given in PG-38.4 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32PG-42.1 Welding End Transitions Maximum Envelope. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35PG-46.2 Acceptable Proportions for Ends of Through-Stays . . . . . . . . . . . . . . . . . . . . . . . . . . . 37PG-52.1 Diagram for Determining the Efficiency of Longitudinal and Diagonal

Ligaments Between Openings in Cylindrical Shells . . . . . . . . . . . . . . . . . . . . . . . . . 39PG-52.2 Example of Tube Spacing With Pitch of Holes Equal in Every Row. . . . . . . . . . . . 40PG-52.3 Example of Tube Spacing With Pitch of Holes Unequal in Every Second

Row . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40PG-52.4 Example of Tube Spacing With Pitch of Holes Varying in Every Second and

Third Row . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40PG-52.5 Example of Tube Spacing With Tube Holes on Diagonal Lines . . . . . . . . . . . . . . . . 40PG-52.6 Diagram for Determining Equivalent Longitudinal Efficiency of Diagonal

Ligaments Between Openings in Cylindrical Shells . . . . . . . . . . . . . . . . . . . . . . . . . 42PG-58.3.1(a) Code Jurisdictional Limits for Piping — Drum Type Boilers . . . . . . . . . . . . . . . . . . 43PG-58.3.1(b) Code Jurisdictional Limits for Piping — Isolable Economizers Located in

Feedwater Piping and Osolable Superheaters in Main Steam Piping . . . . . . . . . . 44PG-58.3.1(c) Code Jurisdictional Limits for Piping — Reheaters and Nonintegral Separately

Fired Superheaters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45PG-58.3.2 Code Jurisdictional Limits for Piping — An Example of Forced-Flow Steam

Generators With No Fixed Steam or Waterline . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46PG-58.3.3 Code Jurisdictional Limits for Piping — An Example of Steam Separator

Type Forced-Flow Steam Generators With No Fixed Steam or Waterline . . . . . 47PG-59.1 Typical Boiler Bushings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49PG-60.3.7 Y-Type Globe Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52PG-60.3.9 Typical Arrangement of Steam and Water Connections for a Water Column . . . . 53PG-67.4 Requirements for Overpressure Protection Forced-Flow Steam Generator . . . . . . . 56PG-80 Maximum Permissible Deviation From a Circular Form, e, for Cylindrical

Parts Under External Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73PG-105.1 Official Symbols for Stamps to Denote The American Society of

Mechanical Engineers’ Standard for Boilers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76PG-105.2 Official Symbol for Stamp to Denote The American Society of Mechanical

Engineers’ Standard for Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76PG-105.3 Official Symbol for Stamp to Denote The American Society of Mechanical

Engineers’ Standard for Welded Piping. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76

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PG-105.4 Official Symbol for Stamp to Denote The American Society of MechanicalEngineers’ Standard for Boiler Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . 77

PG-106 Form of Stamping . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 79

TablesPG-19 Post Cold-Forming Strain Limits and Heat-Treatment Requirements . . . . . . . . . . . . 12PG-20 Post Cold-Forming Strain Limits and Heat-Treatment Requirements . . . . . . . . . . . . 13PG-26 Weld Strength Reduction Factors to Be Applied When Calculating Maximum

Allowable Working Pressure or Minimum Required Thickness ofComponents Fabricated With a Longitudinal Seam Weld. . . . . . . . . . . . . . . . . . . . 16

PG-39 Minimum Number of Threads Per Connection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33PG-68.7 Superheat Correction Factor, Ksh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59PG-68.7M Superheat Correction Factor, Ksh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60PG-69.2.3 Supercritical Correction Factor, Ksc . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64PG-69.2.3M Supercritical Correction Factor, Ksc . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66

PART PW REQUIREMENTS FOR BOILERS FABRICATED BY WELDING . . . . . . . . 86

General

PW-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 86

Materials

PW-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 86

Design

PW-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87PW-9 Design of Welded Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87PW-10 Heat Treatment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88PW-11 Volumetric Examination of Welded Butt Joints. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88PW-13 Head-to-Flange Requirements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88PW-14 Openings in or Adjacent to Welds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90PW-15 Welded Connections . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90PW-16 Minimum Requirements for Attachment Welds. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90PW-19 Welded-In Stays . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97

Fabrication

PW-26 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97PW-27 Welding Processes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97PW-28 Welding Qualification and Weld Records . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 98PW-29 Base Metal Preparation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100PW-31 Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100PW-33 Alignment Tolerance, Shells and Vessels (Including Pipe or Tube Used as a

Shell) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100PW-34 Alignment, Tube and Pipe. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100PW-35 Finished Longitudinal and Circumferential Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100PW-36 Miscellaneous Welding Requirements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101PW-38 Preheating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101PW-39 Requirements for Postweld Heat Treatment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101PW-40 Repair of Defects . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 112PW-41 Circumferential Joints in Pipes, Tubes, and Headers . . . . . . . . . . . . . . . . . . . . . . . . . . 113PW-42 Joints in Valves and Other Boiler Appurtenances . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114PW-43 Loading on Structural Attachments. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114PW-44 Fabrication Rules for Bimetallic Tubes When the Clad Strength Is Included. . . . . 115

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PW-46 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118PW-47 Check of Welding Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118PW-48 Check of Welder and Welding Operator Performance Qualifications. . . . . . . . . . . . 118PW-49 Check of Heat Treatment Practice. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 119PW-50 Qualification of Nondestructive Examination Personnel . . . . . . . . . . . . . . . . . . . . . . . 119PW-51 Radiographic Examination . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 119PW-52 Ultrasonic Examination . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 119PW-53 Test Plates. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 120PW-54 Hydrostatic Test. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122

FiguresPW-9.1 Butt Welding of Plates of Unequal Thickness . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87PW-9.2 Prohibited Welded Joint. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88PW-15 Examples of Weld Strength Calculations. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 91PW-16.1 Some Acceptable Types of Welded Nozzles and Other Connections to

Shells, Drums, and Headers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92PW-16.2 Some Acceptable Forms of Welds for Lugs, Hangers, and Brackets on

Shells, Drums, and Headers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 96PW-19.4(a) Some Acceptable Types of Diagonal Braces for Installation by Welding . . . . . . . . 98PW-19.4(b) Unacceptable Types of Diagonal Braces for Installation by Welding. . . . . . . . . . . . 98PW-43.1 Method of Computation of Attachments to Tubes . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114PW-43.2 Chart for Determining Load Factor, L f . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 116PW-53.1 Test Specimens From Longitudinal Welded Test Plates . . . . . . . . . . . . . . . . . . . . . . . 121PW-53.2 Method of Forming Longitudinal Test Plates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 121PW-53.3(a) Details of Tension Test Specimens . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 123PW-53.3(b) Details of Bend Test Specimens . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 124

TablesPW-11 Required Volumetric Examination of Welded Butt Joints. . . . . . . . . . . . . . . . . . . . . . 89PW-33 Alignment Tolerance of Sections to Be Butt Welded. . . . . . . . . . . . . . . . . . . . . . . . . . 100PW-39 Mandatory Requirements for Postweld Heat Treatment of Pressure Parts and

Attachments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 103PW-39.1 Alternate Postweld Heat Treatment Requirements for Carbon and Low Alloy

Steels . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 112PW-43.1 Tube Attachment Angle Design Factor, K . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 116

PART PR REQUIREMENTS FOR BOILERS FABRICATED BY RIVETING . . . . . . . . 125PART PB REQUIREMENTS FOR BOILERS FABRICATED BY BRAZING . . . . . . . . . 126

General

PB-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 126

Materials

PB-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127PB-6 Brazing Filler Metals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127PB-7 Fluxes and Atmospheres . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127

Design

PB-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127PB-9 Strength of Brazed Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127PB-10 Brazed Joint Efficiency . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128PB-14 Application of Brazing Filler Metal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128PB-15 Permissible Types of Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128

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PB-16 Joint Clearance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128PB-17 Joint Brazing Procedure. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128PB-18 Openings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128PB-19 Brazed Connections . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128

Fabrication

PB-26 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129PB-28 Qualification of Brazing Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129PB-29 Qualification of Brazers and Brazing Operators. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130PB-30 Cleaning of Surfaces to Be Brazed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130PB-31 Clearance Between Surfaces to Be Brazed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130PB-32 Postbrazing Operations. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130PB-33 Repair of Defective Brazing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130


PB-46 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130PB-47 Check of Brazing Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130PB-48 Brazer and Brazing Operator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131PB-49 Visual Examination. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131PB-50 Exemptions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131

Marking and Reports

PB-51 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131

FigurePB-15 Some Acceptable Types of Brazed Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129

TablesPB-1 Maximum Design Temperatures [°F (°C)] for Brazing Filler Metal . . . . . . . . . . . . . 127PB-16 Recommended Joint Clearance at Brazing Temperature . . . . . . . . . . . . . . . . . . . . . . . 129

PART PWT REQUIREMENTS FOR WATERTUBE BOILERS . . . . . . . . . . . . . . . . . . . . . . . . 132

General

PWT-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132

Materials

PWT-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132

Design

PWT-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132PWT-9 Tubes and Pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132PWT-11 Tube Connections . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132PWT-12 Staybolting Box-Type Headers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134PWT-13 Staying Segment of Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134PWT-14 Firing Doors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134PWT-15 Access and Firing Doors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134

FiguresPWT-11 Examples of Acceptable Forms of Tube Attachment . . . . . . . . . . . . . . . . . . . . . . . . . . 133PWT-12.1 Box-Type Header Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134PWT-12.2 Method of Forming Waterleg Joints by Welding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134

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PART PFT REQUIREMENTS FOR FIRETUBE BOILERS . . . . . . . . . . . . . . . . . . . . . . . . . . . 135

General

PFT-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135

Materials

PFT-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135

Design

PFT-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135PFT-9 Thickness Requirements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135PFT-10 Shell Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135PFT-11 Attachment of Heads and Tubesheets. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135PFT-12 Tubes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 136

Combustion Chambers

PFT-13 Combustion Chamber Tubesheet . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 137PFT-14 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138PFT-15 Plain Circular Furnaces . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138PFT-17 Ring-Reinforced Type . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138PFT-18 Corrugated Furnaces . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 139PFT-19 Combined Plain Circular and Corrugated Type . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 139PFT-20 Attachment of Furnaces . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140PFT-21 Fireboxes and Waterlegs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140

Stayed Surfaces

PFT-22 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 141PFT-23 Working Pressure for Stayed Curved Surfaces. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 141PFT-24 Staying Horizontal Return Tube Boilers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143PFT-25 Staying Segments of Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143PFT-26 Area Supported by Stay. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143PFT-27 Maximum Spacing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143PFT-28 Staybolts and Stays . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145PFT-29 Flexible Staybolts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145PFT-30 Crown Bars and Girder Stays. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145PFT-31 Stay Tubes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 146PFT-32 Stresses in Diagonal Stays . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 146

Doors and Openings

PFT-40 Welded Door Openings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 146PFT-41 Openings in Wrapper Sheets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147PFT-42 Fireside Access Openings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147PFT-43 Requirements for Inspection Openings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147PFT-44 Opening Between Boiler and Pressure Relief Valve. . . . . . . . . . . . . . . . . . . . . . . . . . . 147

Domes

PFT-45 Requirements for Domes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147

Setting

PFT-46 Method of Support . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 148

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Piping, Fittings, and Appliances

PFT-47 Water Level Indicators. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149PFT-48 Feed Piping. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149PFT-49 Blowoff Piping. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149PFT-50 Thickness of Furnaces and Tubes Under External Pressure . . . . . . . . . . . . . . . . . . . . 149PFT-51 Maximum Allowable Working Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150PFT-52 Fusible Plugs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 151

FiguresPFT-12.1 Some Acceptable Forms of Tube Attachment on Firetube Boilers . . . . . . . . . . . . . . 136PFT-17.2 Acceptable Type of Ring-Reinforced Furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138PFT-18.1 Morison Furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 139PFT-19 Connection Between Plain and Corrugated Furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . 140PFT-20 Welding Ogee Ring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140PFT-21 Some Acceptable Methods of Forming Waterleg Joints by Welding . . . . . . . . . . . . 141PFT-23.1 Stayed Wrapper Sheet of Locomotive-Type Boiler. . . . . . . . . . . . . . . . . . . . . . . . . . . . 142PFT-25 Example of Staying of Heads Adjacent to Cylindrical Furnaces . . . . . . . . . . . . . . . . 143PFT-27 Pitch of Staybolts Adjacent to Upper Corners of Fireboxes . . . . . . . . . . . . . . . . . . . . 144PFT-32 Measurements for Determining Stresses in Diagonal Stays . . . . . . . . . . . . . . . . . . . . 146PFT-46.1 Spacing and Weld Details for Wall-Support Lugs Set in Pairs on

Horizontal-Return Tubular Boilers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 148PFT-46.2 Welded Bracket Connection for Horizontal-Return Tubular Boilers. . . . . . . . . . . . . 149

PART PFH OPTIONAL REQUIREMENTS FOR FEEDWATER HEATER (WHENLOCATED WITHIN SCOPE OF SECTION I RULES). . . . . . . . . . . . . . . . . . 152

PFH-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152

PART PMB REQUIREMENTS FOR MINIATURE BOILERS . . . . . . . . . . . . . . . . . . . . . . . . . 153

General

PMB-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153PMB-2 Scope . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153

Materials

PMB-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153

Design

PMB-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153PMB-9 Welding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153PMB-10 Washout Openings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-11 Feedwater Supply . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-12 Blowoff . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-13 Water Gages . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-14 Fixtures and Fittings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-15 Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-16 Steam Stop Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-17 Automatic Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PMB-21 Hydrostatic Tests and Inspection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154

PART PEB REQUIREMENTS FOR ELECTRIC BOILERS . . . . . . . . . . . . . . . . . . . . . . . . . . . 156

General

PEB-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156PEB-2 Scope . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156PEB-3 Optional Requirements for the Boiler Pressure Vessel. . . . . . . . . . . . . . . . . . . . . . . . . 156

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Materials

PEB-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156

Design

PEB-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-9 Welding . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-10 Inspection Openings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-11 Feedwater Supply . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-12 Blowoff . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-13 Water Level Indicators. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-14 Pressure Gages. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-15 Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157PEB-16 Automatic Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158PEB-17 Hydrostatic Test. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158PEB-18 Inspection and Stamping of Boilers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158PEB-19 Manufacturer’s Data Report for Electric Boilers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 159

PART PVG REQUIREMENTS FOR ORGANIC FLUID VAPORIZERS . . . . . . . . . . . . . . . 160

General

PVG-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160

Materials

PVG-5 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160

Design

PVG-8 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160PVG-9 General Requirements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160PVG-10 Gage Glasses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160PVG-11 Drain Valves. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160PVG-12 Pressure Relief Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160

FigurePVG-12 Constant, C, for Vapor Related to Ratio of Specific Heats (k p cp/cv) . . . . . . . . . . 161

PART PHRSG REQUIREMENTS FOR HEAT RECOVERY STEAM GENERATORS . . . . 162PHRSG-1 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 162PHRSG-2 Scope . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 162PHRSG-3 Requirements for Superheater and Reheater Condensate Removal

Connections . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 162PHRSG-4 Desuperheater Drain Pots . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 162PHRSG-5 Certification . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164

FigurePHRSG-4 Some Acceptable Desuperheater Spraywater Protection Device

Arrangements. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163

Table

PHRSG-4 Minimum Drain Pot Size. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164

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MANDATORY APPENDICES

I Submittal of Technical Inquiries to the Boiler and Pressure VesselCommittee . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 165

II Standard Units for Use in Equations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 167III Criteria for Reapplication of an ASME Code Symbol Stamp. . . . . . . . . . . . . . . . . . . 168

NONMANDATORY APPENDIX

A Explanation of the Code Containing Matter Not Mandatory UnlessSpecifically Referred to in the Rules of the Code. . . . . . . . . . . . . . . . . . . . . . . . . . . 174

Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 264

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2010 ASMEBOILER AND PRESSURE VESSEL CODE

SECTIONS

I Rules for Construction of Power Boilers

II MaterialsPart A — Ferrous Material SpecificationsPart B — Nonferrous Material SpecificationsPart C — Specifications for Welding Rods, Electrodes, and Filler MetalsPart D — Properties (Customary)Part D — Properties (Metric)

III Rules for Construction of Nuclear Facility ComponentsSubsection NCA — General Requirements for Division 1 and Division 2Division 1Subsection NB — Class 1 ComponentsSubsection NC — Class 2 ComponentsSubsection ND — Class 3 ComponentsSubsection NE — Class MC ComponentsSubsection NF — SupportsSubsection NG — Core Support StructuresSubsection NH — Class 1 Components in Elevated Temperature ServiceAppendices

Division 2 — Code for Concrete Containments

Division 3 — Containments for Transportation and Storage of Spent Nuclear Fueland High Level Radioactive Material and Waste

IV Rules for Construction of Heating Boilers

V Nondestructive Examination

VI Recommended Rules for the Care and Operation of Heating Boilers

VII Recommended Guidelines for the Care of Power Boilers

VIII Rules for Construction of Pressure VesselsDivision 1Division 2 — Alternative RulesDivision 3 — Alternative Rules for Construction of High Pressure Vessels

IX Welding and Brazing Qualifications

X Fiber-Reinforced Plastic Pressure Vessels

XI Rules for Inservice Inspection of Nuclear Power Plant Components

XII Rules for Construction and Continued Service of Transport Tanks

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ADDENDA

Addenda, which include additions and revisions to indi-vidual Sections of the Code, will be sent automatically topurchasers of the applicable Sections up to the publicationof the 2013 Code. The 2010 Code is available only in theloose-leaf format; accordingly, the Addenda will be issuedin the loose-leaf, replacement-page format.

INTERPRETATIONS

ASME issues written replies to inquiries concerninginterpretation of technical aspects of the Code. The Inter-pretations for each individual Section will be publishedseparately and will be included as part of the update serviceto that Section. Interpretations of Section III, Divisions 1

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and 2, will be included with the update service to Subsec-tion NCA.

Interpretations of the Code are posted in January andJuly at www.cstools.asme.org/interpretations.

CODE CASES

The Boiler and Pressure Vessel Committee meets regu-larly to consider proposed additions and revisions to theCode and to formulate Cases to clarify the intent of existingrequirements or provide, when the need is urgent, rulesfor materials or constructions not covered by existing Coderules. Those Cases that have been adopted will appearin the appropriate 2010 Code Cases book: “Boilers andPressure Vessels” and “Nuclear Components.” Supple-ments will be sent automatically to the purchasers of theCode Cases books up to the publication of the 2013 Code.



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FOREWORD

The American Society of Mechanical Engineers set up acommittee in 1911 for the purpose of formulating standardrules for the construction of steam boilers and other pres-sure vessels. This committee is now called the Boiler andPressure Vessel Committee.

The Committee’s function is to establish rules of safety,relating only to pressure integrity, governing the construc-tion1 of boilers, pressure vessels, transport tanks andnuclear components, and inservice inspection for pressureintegrity of nuclear components and transport tanks, andto interpret these rules when questions arise regarding theirintent. This code does not address other safety issues relat-ing to the construction of boilers, pressure vessels, transporttanks and nuclear components, and the inservice inspectionof nuclear components and transport tanks. The user ofthe Code should refer to other pertinent codes, standards,laws, regulations, or other relevant documents. With fewexceptions, the rules do not, of practical necessity, reflectthe likelihood and consequences of deterioration in servicerelated to specific service fluids or external operating envi-ronments. Recognizing this, the Committee has approveda wide variety of construction rules in this Section to allowthe user or his designee to select those which will providea pressure vessel having a margin for deterioration in ser-vice so as to give a reasonably long, safe period of use-fulness. Accordingly, it is not intended that this Sectionbe used as a design handbook; rather, engineering judgmentmust be employed in the selection of those sets of Coderules suitable to any specific service or need.

This Code contains mandatory requirements, specificprohibitions, and nonmandatory guidance for constructionactivities. The Code does not address all aspects of theseactivities and those aspects which are not specificallyaddressed should not be considered prohibited. The Codeis not a handbook and cannot replace education, experi-ence, and the use of engineering judgment. The phraseengineering judgment refers to technical judgments madeby knowledgeable designers experienced in the applicationof the Code. Engineering judgments must be consistentwith Code philosophy and such judgments must neverbe used to overrule mandatory requirements or specificprohibitions of the Code.

1 Construction, as used in this Foreword, is an all-inclusive term com-prising materials, design, fabrication, examination, inspection, testing,certification, and pressure relief.

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The Committee recognizes that tools and techniquesused for design and analysis change as technology prog-resses and expects engineers to use good judgment in theapplication of these tools. The designer is responsible forcomplying with Code rules and demonstrating compliancewith Code equations when such equations are mandatory.The Code neither requires nor prohibits the use of comput-ers for the design or analysis of components constructedto the requirements of the Code. However, designers andengineers using computer programs for design or analysisare cautioned that they are responsible for all technicalassumptions inherent in the programs they use and theyare responsible for the application of these programs totheir design.

The Code does not fully address tolerances. Whendimensions, sizes, or other parameters are not specifiedwith tolerances, the values of these parameters are consid-ered nominal and allowable tolerances or local variancesmay be considered acceptable when based on engineeringjudgment and standard practices as determined by thedesigner.

The Boiler and Pressure Vessel Committee deals withthe care and inspection of boilers and pressure vessels inservice only to the extent of providing suggested rules ofgood practice as an aid to owners and their inspectors.

The rules established by the Committee are not to beinterpreted as approving, recommending, or endorsing anyproprietary or specific design or as limiting in any way themanufacturer’s freedom to choose any method of designor any form of construction that conforms to the Code rules.

The Boiler and Pressure Vessel Committee meets regu-larly to consider revisions of the rules, new rules as dictatedby technological development, Code Cases, and requestsfor interpretations. Only the Boiler and Pressure VesselCommittee has the authority to provide official interpreta-tions of this Code. Requests for revisions, new rules, CodeCases, or interpretations shall be addressed to the Secretaryin writing and shall give full particulars in order to receiveconsideration and action (see Mandatory Appendix cov-ering preparation of technical inquiries). Proposed revi-sions to the Code resulting from inquiries will be presentedto the Main Committee for appropriate action. The actionof the Main Committee becomes effective only after con-firmation by letter ballot of the Committee and approvalby ASME.

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Proposed revisions to the Code approved by the Commit-tee are submitted to the American National Standards Insti-tute and published at http://cstools.asme.org/csconnect/public/index.cfm?PublicReviewpRevisions to invite com-ments from all interested persons. After the allotted timefor public review and final approval by ASME, revisionsare published in updates to the Code.

Code Cases may be used in the construction of compo-nents to be stamped with the ASME Code symbol begin-ning with the date of their approval by ASME.

After Code revisions are approved by ASME, they maybe used beginning with the date of issuance. Revisions,except for revisions to material specifications in SectionII, Parts A and B, become mandatory six months after suchdate of issuance, except for boilers or pressure vesselscontracted for prior to the end of the six-month period.Revisions to material specifications are originated by theAmerican Society for Testing and Materials (ASTM) andother recognized national or international organizations,and are usually adopted by ASME. However, those revi-sions may or may not have any effect on the suitability ofmaterial, produced to earlier editions of specifications, foruse in ASME construction. ASME material specificationsapproved for use in each construction Code are listed inthe Guidelines for Acceptable ASTM Editions and in theGuidelines for Acceptable Non-ASTM Editions, in SectionII, Parts A and B. These Guidelines list, for each specifica-tion, the latest edition adopted by ASME, and earlier andlater editions considered by ASME to be identical forASME construction.

The Boiler and Pressure Vessel Committee in the formu-lation of its rules and in the establishment of maximumdesign and operating pressures considers materials, con-struction, methods of fabrication, inspection, and safetydevices.

The Code Committee does not rule on whether a compo-nent shall or shall not be constructed to the provisions ofthe Code. The Scope of each Section has been establishedto identify the components and parameters considered bythe Committee in formulating the Code rules.

Questions or issues regarding compliance of a specificcomponent with the Code rules are to be directed to theASME Certificate Holder (Manufacturer). Inquiries con-cerning the interpretation of the Code are to be directed

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to the ASME Boiler and Pressure Vessel Committee.ASME is to be notified should questions arise concerningimproper use of an ASME Code symbol.

The specifications for materials given in Section II areidentical with or similar to those of specifications publishedby ASTM, AWS, and other recognized national or interna-tional organizations. When reference is made in an ASMEmaterial specification to a non-ASME specification forwhich a companion ASME specification exists, the refer-ence shall be interpreted as applying to the ASME materialspecification. Not all materials included in the materialspecifications in Section II have been adopted for Codeuse. Usage is limited to those materials and grades adoptedby at least one of the other Sections of the Code for applica-tion under rules of that Section. All materials allowed bythese various Sections and used for construction within thescope of their rules shall be furnished in accordance withmaterial specifications contained in Section II or referencedin the Guidelines for Acceptable Editions in Section II,Parts A and B, except where otherwise provided in CodeCases or in the applicable Section of the Code. Materialscovered by these specifications are acceptable for use initems covered by the Code Sections only to the degreeindicated in the applicable Section. Materials for Code useshould preferably be ordered, produced, and documentedon this basis; Guidelines for Acceptable Editions inSection II, Part A and Guidelines for Acceptable Editionsin Section II, Part B list editions of ASME and year datesof specifications that meet ASME requirements and whichmay be used in Code construction. Material produced toan acceptable specification with requirements differentfrom the requirements of the corresponding specificationslisted in the Guidelines for Acceptable Editions in Part Aor Part B may also be used in accordance with the above,provided the material manufacturer or vessel manufacturercertifies with evidence acceptable to the Authorized Inspec-tor that the corresponding requirements of specificationslisted in the Guidelines for Acceptable Editions in Part Aor Part B have been met. Material produced to an acceptablematerial specification is not limited as to country of origin.

When required by context in this Section, the singularshall be interpreted as the plural, and vice-versa; and thefeminine, masculine, or neuter gender shall be treated assuch other gender as appropriate.



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STATEMENT OF POLICY

ON THE USE OF CODE SYMBOLS AND

CODE AUTHORIZATION IN ADVERTISING

ASME has established procedures to authorize qualifiedorganizations to perform various activities in accordancewith the requirements of the ASME Boiler and PressureVessel Code. It is the aim of the Society to provide recogni-tion of organizations so authorized. An organization hold-ing authorization to perform various activities inaccordance with the requirements of the Code may statethis capability in its advertising literature.

Organizations that are authorized to use Code Symbolsfor marking items or constructions that have been con-structed and inspected in compliance with the ASME Boilerand Pressure Vessel Code are issued Certificates of Autho-rization. It is the aim of the Society to maintain the standingof the Code Symbols for the benefit of the users, theenforcement jurisdictions, and the holders of the symbolswho comply with all requirements.

Based on these objectives, the following policy has beenestablished on the usage in advertising of facsimiles of thesymbols, Certificates of Authorization, and reference toCode construction. The American Society of Mechanical

STATEMENT OF POLICY

ON THE USE OF ASME MARKING

TO IDENTIFY MANUFACTURED ITEMS

The ASME Boiler and Pressure Vessel Code providesrules for the construction of boilers, pressure vessels, andnuclear components. This includes requirements for mate-rials, design, fabrication, examination, inspection, andstamping. Items constructed in accordance with all of theapplicable rules of the Code are identified with the officialCode Symbol Stamp described in the governing Sectionof the Code.

Markings such as “ASME,” “ASME Standard,” or anyother marking including “ASME” or the various Code

xvii

Engineers does not “approve,” “certify,” “rate,” or“endorse” any item, construction, or activity and there shallbe no statements or implications that might so indicate. Anorganization holding a Code Symbol and/or a Certificate ofAuthorization may state in advertising literature that items,constructions, or activities “are built (produced or per-formed) or activities conducted in accordance with therequirements of the ASME Boiler and Pressure VesselCode,” or “meet the requirements of the ASME Boiler andPressure Vessel Code.” An ASME corporate logo shall notbe used by any organization other than ASME.

The ASME Symbol shall be used only for stamping andnameplates as specifically provided in the Code. However,facsimiles may be used for the purpose of fostering theuse of such construction. Such usage may be by an associa-tion or a society, or by a holder of a Code Symbol whomay also use the facsimile in advertising to show thatclearly specified items will carry the symbol. General usageis permitted only when all of a manufacturer’s items areconstructed under the rules.

Symbols shall not be used on any item that is not con-structed in accordance with all of the applicable require-ments of the Code.

Items shall not be described on ASME Data ReportForms nor on similar forms referring to ASME that tendto imply that all Code requirements have been met when,in fact, they have not been. Data Report Forms coveringitems not fully complying with ASME requirements shouldnot refer to ASME or they should clearly identify all excep-tions to the ASME requirements.

(10)



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PERSONNELASME Boiler and Pressure Vessel Standards Committees,

Subgroups, and Working GroupsAs of January 1, 2010

TECHNICAL OVERSIGHT MANAGEMENT COMMITTEE (TOMC)

J. G. Feldstein, Chair J. F. HenryT. P. Pastor, Vice Chair C. L. HoffmannJ. S. Brzuszkiewicz, Staff G. G. Karcher

Secretary W. M. LundyR. W. Barnes J. R. MacKayR. J. Basile U. R. MillerJ. E. Batey P. A. MolvieD. L. Berger W. E. NorrisM. N. Bressler G. C. ParkD. A. Canonico M. D. RanaR. P. Deubler B. W. RobertsD. A. Douin S. C. RobertsD. Eisberg F. J. Schaaf, Jr.R. E. Gimple A. SelzM. Gold R. W. SwayneT. E. Hansen

HONORARY MEMBERS (MAIN COMMITTEE)

F. P. Barton M. H. JawadR. J. Cepluch A. J. JustinL. J. Chockie W. G. KnechtT. M. Cullen J. LeCoffW. D. Doty T. G. McCartyJ. R. Farr G. C. MillmanG. E. Feigel R. A. MoenR. C. Griffin R. F. ReedyO. F. Hedden K. K. TamE. J. Hemzy L. P. Zick, Jr.

ADMINISTRATIVE COMMITTEE

J. S. Brzuszkiewicz, Staff J. G. FeldsteinSecretary J. F. Henry

R. W. Barnes P. A. MolvieJ. E. Batey G. C. ParkD. L. Berger T. P. PastorD. Eisberg A. Selz

HONORS AND AWARDS COMMITTEE

M. Gold, Chair W. L. Haag, Jr.F. E. Gregor, Vice Chair S. F. Harrison, Jr.T. Schellens, Staff Secretary R. M. JesseeD. R. Sharp, Staff Secretary W. C. LaRochelleR. J. Basile T. P. PastorJ. E. Batey A. SelzD. L. Berger R. R. StevensonJ. G. Feldstein

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MARINE CONFERENCE GROUP

H. N. Patel, Chair G. PallichadathJ. G. Hungerbuhler, Jr. J. D. Reynolds

CONFERENCE COMMITTEE

R. J. Aben, Jr. — Michigan M. R. Klosterman — Iowa(Chair) M. Kotb — Quebec, Canada

R. D. Reetz — North Dakota K. J. Kraft — Maryland(Vice Chair) B. Krasiun — Saskatchewan,

D. A. Douin — Ohio Canada(Secretary) K. T. Lau — Alberta, Canada

J. S. Aclaro — California G. Lemay — Ontario, CanadaJ. T. Amato — Minnesota W. McGivney — New YorkB. P. Anthony — Rhode Island T. J. Monroe — OklahomaR. D. Austin — Arizona G. R. Myrick — ArkansasE. W. Bachellier — Nunavut, S. V. Nelson — Colorado

Canada W. R. Owens — LouisianaB. F. Bailey — Illinois R. P. Pate — AlabamaJ. E. Bell — Michigan R. L. Perry — NevadaW. K. Brigham — New H. D. Pfaff — South Dakota

Hampshire A. E. Platt — ConnecticutM. A. Burns — Florida J. F. Porcella — West VirginiaJ. H. Burpee — Maine M. R. Poulin — IdahoC. B. Cantrell — Nebraska D. C. Price — YukonD. C. Cook — California Territory, CanadaJ. A. Davenport — R. S. Pucek — Wisconsin

Pennsylvania T. W. Rieger — Manitoba,S. Donovan — Northwest Canada

Territories, Canada A. E. Rogers — TennesseeD. Eastman — Newfoundland D. E. Ross — New Brunswick,

and Labrador, Canada CanadaE. Everett — Georgia K. A. Rudolph — HawaiiC. Fulton — Alaska M. J. Ryan — IllinoisJ. M. Given, Jr. — North G. Scribner — Missouri

Carolina J. G. Siggers — BritishM. Graham — Oregon Columbia, CanadaR. J. Handy — Kentucky T. Stewart — MontanaJ. B. Harlan — Delaware R. K. Sturm — UtahE. G. Hilton — Virginia M. J. Verhagen — WisconsinK. Hynes — Prince Edward P. L. Vescio, Jr. — New York

Island, Canada M. Washington — New JerseyD. T. Jagger — Ohio K. L. Watson — MississippiD. J. Jenkins — Kansas L. Williamson — WashingtonA. P. Jones — Texas D. J. Willis — IndianaE. S. Kawa, Jr. —

Massachusetts



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INTERNATIONAL INTEREST REVIEW GROUP

V. Felix C. MinuY.-G. Kim Y.-W. ParkS. H. Leong R. ReynagaW. Lin P. WilliamsonO. F. Manafa

PROJECT TEAM ON HYDROGEN TANKS

M. D. Rana, Chair C. T. I. WebsterA. P. Amato, Staff Secretary R. C. Biel, ContributingF. L. Brown MemberD. A. Canonico J. Birdsall, ContributingD. C. Cook MemberJ. Coursen M. Duncan, ContributingJ. W. Felbaum MemberB. D. Hawkes D. R. Frikken, ContributingN. L. Newhouse MemberA. S. Olivares L. E. Hayden, Jr., ContributingG. B. Rawls, Jr. MemberB. F. Shelley K. T. Lau, ContributingJ. R. Sims, Jr. MemberN. Sirosh K. Oyamada, ContributingJ. H. Smith MemberS. Staniszewski C. H. Rivkin, ContributingR. Subramanian MemberT. Tahara C. San Marchi, ContributingD. W. Treadwell MemberE. Upitis B. Somerday, ContributingY. Wada Member

COMMITTEE ON POWER BOILERS (I)

D. L. Berger, Chair T. C. McGoughR. E. McLaughlin, Vice Chair P. A. MolvieU. D’Urso, Staff Secretary Y. OishiJ. L. Arnold J. T. PillowS. W. Cameron B. W. RobertsD. A. Canonico R. D. Schueler, Jr.K. K. Coleman J. P. Swezy, Jr.P. D. Edwards J. M. TanzoshP. Fallouey R. V. WielgoszinskiJ. G. Feldstein D. J. WillisG. W. Galanes G. Ardizzoia, DelegateT. E. Hansen H. Michael, DelegateJ. F. Henry E. M. Ortman, AlternateJ. S. Hunter D. N. French, HonoraryW. L. Lowry MemberJ. R. MacKay R. L. Williams, HonoraryF. Massi Member

Subgroup on Design (BPV I)

P. A. Molvie, Chair B. W. MooreJ. Vattappilly, Secretary R. D. Schueler, Jr.D. I. Anderson J. L. SeigleP. Dhorajia J. P. Swezy, Jr.J. P. Glaspie S. V. TorkildsonG. B. Komora G. Ardizzoia, DelegateJ. C. Light

xix

Subgroup on Fabrication and Examination (BPV I)J. T. Pillow, Chair C. T. McDarisG. W. Galanes, Secretary T. C. McGoughJ. L. Arnold R. E. McLaughlinD. L. Berger Y. OishiS. W. Cameron J. P. Swezy, Jr.J. Hainsworth R. V. WielgoszinskiT. E. Hansen

Subgroup on General Requirements (BPV I)R. E. McLaughlin, Chair J. T. PillowF. Massi, Secretary D. TompkinsP. D. Edwards S. V. TorkildsonT. E. Hansen D. E. TuttleW. L. Lowry R. V. WielgoszinskiT. C. McGough D. J. WillisE. M. Ortman

Subgroup on Materials (BPV I)B. W. Roberts, Chair K. L. HayesJ. S. Hunter, Secretary J. F. HenryS. H. Bowes O. X. LiD. A. Canonico J. R. MacKayK. K. Coleman F. MasuyamaP. Fallouey D. W. RahoiG. W. Galanes J. M. Tanzosh

Subgroup on Piping (BPV I)T. E. Hansen, Chair W. L. LowryD. L. Berger F. MassiP. D. Edwards T. C. McGoughG. W. Galanes D. TompkinsT. G. Kosmatka E. A. Whittle

Subgroup on Heat Recovery Steam Generators (BPV I)T. E. Hansen, Chair E. M. OrtmanD. Dziubinski, Secretary R. D. Schueler, Jr.L. R. Douglas J. C. Steverman, Jr.J. Gertz D. TompkinsG. B. Komora S. V. TorkildsonC. T. McDaris B. C. TurczynskiB. W. Moore

COMMITTEE ON MATERIALS (II)J. F. Henry, Chair R. C. SutherlinM. Gold, Vice Chair R. W. SwindemanN. Lobo, Staff Secretary J. M. TanzoshF. Abe B. E. ThurgoodA. Appleton D. Kwon, DelegateM. N. Bressler O. Oldani, DelegateH. D. Bushfield W. R. Apblett, Jr., ContributingJ. Cameron MemberD. A. Canonico E. G. Nisbett, ContributingA. Chaudouet MemberP. Fallouey E. Upitis, ContributingJ. R. Foulds MemberD. W. Gandy T. M. Cullen, HonoraryM. H. Gilkey MemberJ. F. Grubb W. D. Doty, HonoraryC. L. Hoffmann MemberM. Katcher W. D. Edsall, HonoraryP. A. Larkin MemberF. Masuyama G. C. Hsu, Honorary MemberR. K. Nanstad R. A. Moen, HonoraryM. L. Nayyar MemberD. W. Rahoi C. E. Spaeder, Jr., HonoraryB. W. Roberts MemberE. Shapiro A. W. Zeuthen, HonoraryM. H. Skillingberg Member



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Subgroup on External Pressure (BPV II)

R. W. Mikitka, Chair M. KatcherJ. A. A. Morrow, Secretary D. L. KurleL. F. Campbell C. R. ThomasD. S. Griffin C. H. Sturgeon, ContributingJ. F. Grubb MemberJ. R. Harris III

Subgroup on Ferrous Specifications (BPV II)

A. Appleton, Chair L. J. LavezziR. M. Davison W. C. MackB. M. Dingman J. K. MahaneyM. J. Dosdourian R. J. MarciniecP. Fallouey A. S. MelilliT. Graham E. G. NisbettJ. F. Grubb K. E. OrieK. M. Hottle J. ShickD. S. Janikowski E. UpitisD. C. Krouse R. Zawierucha

Subgroup on International Material Specifications (BPV II)

A. Chaudouet, Chair W. M. LundyD. Dziubinski, Secretary A. R. NyweningS. W. Cameron R. D. Schueler, Jr.D. A. Canonico E. UpitisP. Fallouey D. Kwon, DelegateA. F. Garbolevsky O. Oldani, DelegateD. O. Henry H. Lorenz, ContributingM. Ishikawa MemberO. X. Li

Subgroup on Strength, Ferrous Alloys (BPV II)

C. L. Hoffmann, Chair F. MasuyamaJ. M. Tanzosh, Secretary S. MatsumotoF. Abe H. MurakamiW. R. Apblett, Jr. D. W. RahoiD. A. Canonico B. W. RobertsA. Di Rienzo M. S. SheltonP. Fallouey J. P. ShingledeckerJ. R. Foulds M. J. SlaterM. Gold R. W. SwindemanJ. A. Hall B. E. ThurgoodJ. F. Henry T. P. Vassallo, Jr.K. Kimura

Subgroup on Nonferrous Alloys (BPV II)

M. Katcher, Chair H. MatsuoR. C. Sutherlin, Secretary J. A. McMasterW. R. Apblett, Jr. D. W. RahoiM. H. Gilkey E. ShapiroJ. F. Grubb M. H. SkillingbergA. Heino D. TylerJ. Kissell R. ZawieruchaP. A. Larkin H. D. Bushfield, ContributingT. M. Malota MemberS. Matsumoto

Subgroup on Physical Properties (BPV II)

J. F. Grubb, Chair P. FalloueyH. D. Bushfield E. Shapiro

xx

Subgroup on Strength of Weldments (BPV II & BPV IX)

J. M. Tanzosh, Chair K. L. HayesW. F. Newell, Jr., Secretary J. F. HenryS. H. Bowes D. W. RahoiK. K. Coleman B. W. RobertsP. D. Flenner J. P. ShingledeckerJ. R. Foulds W. J. SperkoD. W. Gandy B. E. Thurgood

Special Working Group on Nonmetallic Materials (BPV II)

C. W. Rowley, Chair P. S. HillF. L. Brown M. R. KesslerS. R. Frost F. WorthM. Golliet

COMMITTEE ON CONSTRUCTION OF NUCLEAR FACILITYCOMPONENTS (III)

R. W. Barnes, Chair J. D. StevensonR. M. Jessee, Vice Chair K. R. WichmanC. A. Sanna, Staff Secretary C. S. WithersW. H. Borter Y. H. Choi, DelegateM. N. Bressler T. Ius, DelegateT. D. Burchell C. C. Kim, ContributingJ. R. Cole MemberR. P. Deubler E. B. Branch, HonoraryB. A. Erler MemberG. M. Foster G. D. Cooper, HonoraryR. S. Hill III MemberC. L. Hoffmann W. D. Doty, HonoraryV. Kostarev MemberW. C. LaRochelle D. F. Landers, HonoraryK. A. Manoly MemberW. N. McLean R. A. Moen, HonoraryM. N. Mitchell MemberD. K. Morton C. J. Pieper, HonoraryR. F. Reedy Member

Subgroup on Containment Systems for Spent Fueland High-Level Waste Transport Packagings (BPV III)

G. M. Foster, Chair P. E. McConnellG. J. Solovey, Vice Chair I. D. McInnesD. K. Morton, Secretary A. B. MeichlerD. J. Ammerman R. E. NickellW. G. Beach E. L. PleinsG. Bjorkman T. SaegusaW. H. Borter H. P. ShrivastavaG. R. Cannell N. M. SimpsonE. L. Farrow R. H. SmithR. S. Hill III J. D. StevensonS. Horowitz C. J. TemusD. W. Lewis A. D. WatkinsC. G. May



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Subgroup on Design (BPV III)

R. P. Deubler, Chair D. F. LandersR. S. Hill III, Vice Chair K. A. ManolyA. N. Nguyen, Secretary R. J. MastersonT. M. Adams W. N. McLeanS. Asada J. C. MinichielloM. N. Bressler M. MorishitaC. W. Bruny E. L. PleinsJ. R. Cole I. SaitoR. E. Cornman, Jr. G. C. SlagisA. A. Dermenjian J. D. StevensonP. Hirschberg J. P. TuckerR. I. Jetter K. R. WichmanR. B. Keating J. YangJ. F. Kielb T. Ius, DelegateH. Kobayashi

Working Group on Supports (SG-D) (BPV III)

R. J. Masterson, Chair A. N. NguyenF. J. Birch, Secretary I. SaitoK. Avrithi J. R. StinsonU. S. Bandyopadhyay T. G. TerryahR. P. Deubler G. Z. TokarskiW. P. Golini C.-I. Wu

Working Group on Core Support Structures (SG-D) (BPV III)

J. Yang, Chair H. S. MehtaJ. F. Kielb, Secretary J. F. MulloolyF. G. Al-Chammas A. TsirigotisJ. T. Land

Working Group on Design Methodology (SG-D) (BPV III)

R. B. Keating, Chair J. D. StevensonS. D. Snow, Secretary A. TsirigotisK. Avrithi T. M. WigerM. Basol J. YangD. L. Caldwell D. F. Landers, CorrespondingH. T. Harrison III MemberP. Hirschberg M. K. Au-Yang, ContributingH. Kobayashi MemberH. Lockert R. D. Blevins, ContributingJ. F. McCabe MemberA. N. Nguyen W. S. Lapay, ContributingD. H. Roarty MemberE. A. Rodriguez

Working Group on Design of Division 3 Containments(SG-D) (BPV III)

E. L. Pleins, Chair H. P. ShrivastavaD. J. Ammerman C. J. TemusG. Bjorkman I. D. McInnes, ContributingS. Horowitz MemberD. W. Lewis R. E. Nickell, ContributingJ. C. Minichiello MemberD. K. Morton

xxi

Working Group on Piping (SG-D) (BPV III)

P. Hirschberg, Chair E. R. NelsonG. Z. Tokarski, Secretary A. N. NguyenT. M. Adams N. J. ShahG. A. Antaki M. S. SillsC. Basavaraju G. C. SlagisJ. Catalano N. C. SutherlandJ. R. Cole E. A. WaisM. A. Gray C.-I. WuR. W. Haupt D. F. Landers, CorrespondingJ. Kawahata MemberR. B. Keating R. D. Patel, ContributingV. Kostarev MemberY. Liu E. C. Rodabaugh, ContributingJ. F. McCabe MemberJ. C. Minichiello

Working Group on Probabilistic Methods in Design(SG-D) (BPV III)

R. S. Hill III, Chair M. MorishitaT. Asayama P. J. O’ReganK. Avrithi N. A. PalmB. M. Ayyub I. SaitoA. A. Dermenjian M. E. SchmidtM. R. Graybeal A. TsirigotisD. O. Henry J. P. TuckerS. D. Kulat R. M. WilsonA. McNeill III

Working Group on Pumps (SG-D) (BPV III)

R. E. Cornman, Jr., Chair R. A. LadefianP. W. Behnke J. W. LeavittM. D. Eftychiou R. A. PatrickA. Fraser J. R. RajanR. Ghanbari R. UdoM. Higuchi A. G. WashburnC. J. Jerz

Working Group on Valves (SG-D) (BPV III)

J. P. Tucker, Chair J. O’CallaghanG. A. Jolly J. D. PageW. N. McLean S. N. ShieldsT. A. McMahon H. R. SondereggerC. A. Mizer J. C. Tsacoyeanes

Working Group on Vessels (SG-D) (BPV III)

G. K. Miller, Secretary O.-S. KimC. Basavaraju K. MatsunagaC. W. Bruny D. E. MatthewsJ. V. Gregg C. TuryloW. J. Heilker W. F. WeitzeA. Kalnins R. M. WilsonR. B. Keating

Special Working Group on Environmental Effects (SG-D) (BPV III)

W. Z. Novak, Chair C. L. HoffmannR. S. Hill III Y. H. Choi, Delegate



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Subgroup on General Requirements (BPV III & 3C)

W. C. LaRochelle, Chair M. R. MinickL. M. Plante, Secretary B. B. ScottA. Appleton C. T. SmithJ. R. Berry W. K. Sowder, Jr.J. V. Gardiner D. M. VickeryW. P. Golini D. V. WalsheG. L. Hollinger C. S. WithersE. A. Mayhew H. Michael, DelegateR. P. McIntyre

Working Group on Duties and Responsibilities (SG-GR) (BPV III)

J. V. Gardiner, Chair A. T. KeimG. L. Hollinger, Secretary M. A. LockwoodJ. R. Berry L. M. PlanteM. E. Jennings D. J. RoszmanK. A. Kavanagh S. Scardigno

Working Group on Quality Assurance, Certification, andStamping (SG-GR) (BPV III)

C. T. Smith, Chair M. R. MinickC. S. Withers, Secretary R. B. PatelA. Appleton S. J. SalvadorB. K. Bobo W. K. Sowder, Jr.S. M. Goodwin M. F. SullivanJ. W. Highlands G. E. SzabaturaR. P. McIntyre D. M. Vickery

Subgroup on Materials, Fabrication, and Examination (BPV III)

C. L. Hoffmann, Chair C. C. KimW. G. Beach M. LauW. H. Borter H. MurakamiG. R. Cannell N. M. SimpsonR. H. Davis W. J. SperkoD. M. Doyle J. R. StinsonG. M. Foster J. F. StrunkB. D. Frew K. B. StuckeyG. B. Georgiev A. D. WatkinsS. E. Gingrich H. Michael, DelegateR. M. Jessee

Subgroup on Pressure Relief (BPV III)

J. F. Ball, Chair A. L. SzeglinE. M. Petrosky D. G. Thibault

Subgroup on Strategy and Management(BPV III, Divisions 1 and 2)

R. W. Barnes, Chair E. V. ImbroC. A. Sanna, Staff Secretary R. M. JesseeB. K. Bobo K. A. ManolyN. Broom D. K. MortonJ. R. Cole J. RamirezB. A. Erler R. F. ReedyC. M. Faidy C. T. SmithJ. M. Helmey W. K. Sowder, Jr.M. F. Hessheimer Y. UrabeR. S. Hill III

xxii

Special Working Group on Editing and Review (BPV III)

R. F. Reedy, Chair B. A. ErlerW. H. Borter W. C. LaRochelleM. N. Bressler J. D. StevensonR. P. Deubler

Special Working Group on Polyethylene Pipe (BPV III)

J. C. Minichiello, Chair P. KrishnaswamyT. M. Adams E. LeverW. I. Adams E. W. McElroyG. A. Antaki D. P. MunsonC. Basavaraju T. M. MustoD. Burwell L. J. PetroffJ. M. Craig C. W. RowleyR. R. Croft F. J. Schaaf, Jr.E. L. Farrow C. T. SmithE. M. Focht H. E. SvetlikM. Golliet D. M. VickeryA. N. Haddad Z. J. ZhouR. S. Hill III

Working Group on Nuclear High-TemperatureGas-Cooled Reactors (BPV III)

N. Broom, Chair T. R. LupoldT. D. Burchell D. L. MarriottM. F. Hessheimer D. K. MortonR. S. Hill III T.-L. ShamE. V. Imbro Y. TachibanaR. I. Jetter T. YuharaY. W. Kim

Subgroup on Graphite Core Components (BPV III)

T. D. Burchell, Chair M. P. HindleyC. A. Sanna, Staff Secretary Y. KatohR. L. Bratton M. N. MitchellS.-H. Chi N. N. NemethM. W. Davies T. OkuS. W. Doms T. ShibataS. F. Duffy M. SrinivasanO. Gelineau A. G. SteerG. O. Hayner S. Yu

Subgroup on Industry Experience for New Plants(BPV III & BPV XI)

G. M. Foster, Chair K. MatsunagaJ. T. Lindberg, Chair R. E. McLaughlinH. L. Gustin, Secretary A. McNeill IIIM. L. Coats H. MurakamiA. A. Dermenjian R. D. PatelJ. Fletcher J. C. PoehlerE. B. Gerlach D. W. SanduskyH. L. Gustin R. R. SchaeferD. O. Henry D. M. SwannE. V. Imbro E. R. WillisC. C. Kim C. S. WithersO.-S. Kim S. M. Yee



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Subgroup on Magnetic Confinement Fusion Energy Devices(BPV III)

W. K. Sowder, Jr., Chair S. LeeR. W. Barnes G. LiM. Higuchi X. LiK. H. Jong D. RoszmanK. A. Kavanagh S. J. SalvadorH.-J. Kim

Subgroup on Nuclear High-Temperature Reactors (BPV III)

M. Morishita, Chair G. H. KooR. I. Jetter, Vice Chair D. K. MortonT.-L. Sham, Secretary J. E. NestellN. Broom

Working Group on Fusion Energy Devices (BPV III)

W. K. Sowder, Jr., Chair

Working Group on Liquid Metal Reactors (BPV III)

T.-L. Sham, Chair G. H. KooT. Asayama, Secretary M. LiR. W. Barnes S. MajumdarC. M. Faidy M. MorishitaR. I. Jetter J. E. Nestell

Special Working Group on Bolted Flanged Joints (BPV III)

R. W. Mikitka, Chair W. J. KovesG. D. Bibel M. S. SheltonW. Brown

Subgroup on Design Analysis (BPV III)

G. L. Hollinger, Chair W. J. KovesS. A. Adams K. MatsunagaM. R. Breach G. A. MillerR. G. Brown W. D. ReinhardtT. M. Damiani D. H. RoartyR. J. Gurdal G. SannazzaroB. F. Hantz T. G. SeippC. F. Heberling II G. TaxacherC. E. Hinnant W. F. WeitzeD. P. Jones R. A. WhippleA. Kalnins K. Wright

Subgroup on Elevated Temperature Design (BPV III)

R. I. Jetter, Chair A. B. HullJ. J. Abou-Hanna M. H. JawadT. Asayama G. H. KooC. Becht W. J. KoovesF. W. Brust D. L. MarriottP. Carter T. E. McGreevyJ. F. Cervenka J. E. NestellB. Dogan W. J. O’DonnellD. S. Griffin T.-L. ShamB. F. Hantz R. W. Swindeman

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Subgroup on Fatigue Strength (BPV III)

W. J. O’Donnell, Chair D. P. JonesS. A. Adams G. KharshafdjianG. S. Chakrabarti S. MajumdarT. M. Damiani S. N. MalikP. R. Donavin D. H. RoartyR. J. Gurdal G. TaxacherC. F. Heberling II A. TsirigotisC. E. Hinnant K. WrightP. Hirschberg H. H. Ziada

JOINT ACI-ASME COMMITTEE ONCONCRETE COMPONENTS FOR NUCLEAR SERVICE (BPV 3C)

A. C. Eberhardt, Chair O. JovallC. T. Smith, Vice Chair N.-H. LeeM. L. Vazquez, Staff Secretary J. MunshiN. Alchaar N. OrbovicJ. F. Artuso B. B. ScottH. G. Ashar R. E. ShewmakerC. J. Bang J. D. StevensonB. A. Erler M. K. ThummF. Farzam M. L. WilliamsP. S. Ghosal T. D. Al-Shawaf, ContributingJ. Gutierrez MemberJ. K. Harrold T. Muraki, ContributingG. A. Harstead MemberM. F. Hessheimer M. R. Senecal, ContributingT. C. Inman MemberT. E. Johnson

Working Group on Materials, Fabrication, and Examination(BPV 3C)

J. F. Artuso, Chair J. GutierrezP. S. Ghosal, Vice Chair B. B. ScottM. L. Williams, Secretary C. T. SmithA. C. Eberhardt

Working Group on Modernization (BPV 3C)

N. Alchaar, Chair J. F. ArtusoO. Jovall, Vice Chair J. K. HarroldC. T. Smith, Secretary

COMMITTEE ON HEATING BOILERS (IV)

P. A. Molvie, Chair D. J. JenkinsT. L. Bedeaux, Vice Chair P. A. LarkinG. Moino, Staff Secretary K. M. McTagueJ. Calland B. W. MooreJ. P. Chicoine T. M. ParksC. M. Dove J. L. SeigleB. G. French R. V. WielgoszinskiW. L. Haag, Jr. H. Michael, DelegateJ. A. Hall E. A. Nordstrom, AlternateA. Heino

Subgroup on Care and Operation of Heating Boilers (BPV IV)

K. M. McTague P. A. Molvie



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Subgroup on Cast Iron Boilers (BPV IV)

K. M. McTague, Chair A. P. JonesT. L. Bedeaux, Vice Chair V. G. KleftisJ. P. Chicoine J. KliessB. G. French P. A. LarkinJ. A. Hall E. A. Nordstrom

Subgroup on Materials (BPV IV)

P. A. Larkin, Chair B. J. IskeJ. A. Hall, Vice Chair J. KliessA. Heino J. L. Seigle

Subgroup on Water Heaters (BPV IV)

W. L. Haag, Jr., Chair K. M. McTagueJ. Calland, Vice Chair O. A. MissoumJ. P. Chicoine R. E. OlsonB. G. French F. J. SchreinerT. D. Gantt M. A. TaylorB. J. Iske T. E. TrantA. P. Jones

Subgroup on Welded Boilers (BPV IV)

T. L. Bedeaux, Chair E. A. NordstromJ. Calland, Vice Chair R. E. OlsonC. M. Dove J. L. SeigleB. G. French R. V. WielgoszinskiA. P. Jones H. Michael, Delegate

COMMITTEE ONNONDESTRUCTIVE EXAMINATION (V)

J. E. Batey, Chair A. B. NagelF. B. Kovacs, Vice Chair C. A. NoveJ. Brzuszkiewicz, Staff T. L. Plasek

Secretary F. J. SattlerS. J. Akrin G. M. Gatti, DelegateC. A. Anderson B. H. Clark, Jr., HonoraryJ. E. Aycock MemberA. S. Birks H. C. Graber, HonoraryP. L. Brown MemberN. Y. Faransso O. F. Hedden, HonoraryA. F. Garbolevsky MemberG. W. Hembree J. R. MacKay, HonoraryR. W. Kruzic MemberJ. R. McGimpsey T. G. McCarty, HonoraryM. D. Moles Member

Subgroup on General Requirements/Personnel Qualifications and Inquiries (BPV V)

F. B. Kovacs, Chair G. W. HembreeC. A. Anderson J. W. HoufJ. E. Batey J. R. MacKayA. S. Birks J. P. Swezy, Jr.N. Y. Faransso

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Subgroup on Surface Examination Methods (BPV V)

A. S. Birks, Chair G. W. HembreeS. J. Akrin R. W. KruzicP. L. Brown C. A. NoveB. Caccamise F. J. SattlerN. Y. Faransso F. C. TurnbullN. Farrenbaugh G. M. Gatti, DelegateN. A. Finney

Subgroup on Volumetric Methods (BPV V)

G. W. Hembree, Chair F. B. KovacsS. J. Akrin R. W. KruzicJ. E. Aycock J. R. McGimpseyJ. E. Batey M. D. MolesP. L. Brown A. B. NagelB. Caccamise C. A. NoveN. Y. Faransso T. L. PlasekA. F. Garbolevsky F. J. SattlerR. W. Hardy G. M. Gatti, DelegateR. A. Kellerhall

Working Group on Acoustic Emissions (SG-VM) (BPV V)

N. Y. Faransso, Chair J. E. BateyJ. E. Aycock R. K. Miller

Working Group on Radiography (SG-VM) (BPV V)

F. B. Kovacs, Chair G. W. HembreeS. J. Akrin R. W. KruzicJ. E. Aycock J. R. McGimpseyJ. E. Batey R. J. MillsP. L. Brown A. B. NagelB. Caccamise C. A. NoveN. Y. Faransso T. L. PlasekA. F. Garbolevsky F. C. TurnbullR. W. Hardy D. E. Williams

Working Group on Ultrasonics (SG-VM) (BPV V)

R. W. Kruzic, Chair R. A. KellerhallJ. E. Aycock M. D. MolesB. Caccamise A. B. NagelN. Y. Faransso C. A. NoveN. A. Finney F. J. SattlerO. F. Hedden

COMMITTEE ON PRESSURE VESSELS (VIII)

T. P. Pastor, Chair D. T. PetersU. R. Miller, Vice Chair M. J. PischkeS. J. Rossi, Staff Secretary M. D. RanaT. Schellens, Staff Secretary G. B. Rawls, Jr.R. J. Basile S. C. RobertsJ. Cameron C. D. RoderyD. B. DeMichael A. SelzJ. P. Glaspie J. R. Sims, Jr.M. Gold D. A. SwansonJ. F. Grubb K. K. TamL. E. Hayden, Jr. S. TeradaG. G. Karcher E. UpitisK. T. Lau P. A. McGowan, DelegateJ. S. Lee H. Michael, DelegateR. Mahadeen K. Oyamada, DelegateS. Malone M. E. Papponetti, DelegateR. W. Mikitka D. Rui, DelegateK. Mokhtarian T. Tahara, DelegateC. C. Neely W. S. Jacobs, ContributingT. W. Norton MemberD. A. Osage



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Subgroup on Design (BPV VIII)

U. R. Miller, Chair C. D. RoderyR. J. Basile, Vice Chair A. SelzM. D. Lower, Secretary S. C. ShahO. A. Barsky J. C. SowinskiM. R. Breach C. H. SturgeonF. L. Brown D. A. SwansonJ. R. Farr K. K. TamC. E. Hinnant J. VattappillyM. H. Jawad R. A. WhippleR. W. Mikitka A. H. Gibbs, DelegateK. Mokhtarian K. Oyamada, DelegateD. A. Osage M. E. Papponetti, DelegateT. P. Pastor W. S. Jacobs, CorrespondingM. D. Rana MemberG. B. Rawls, Jr. E. L. Thomas, Jr., HonoraryS. C. Roberts Member

Subgroup on Fabrication and Inspection (BPV VIII)

C. D. Rodery, Chair J. S. LeeJ. P. Swezy, Jr., Vice Chair D. A. OsageB. R. Morelock, Secretary M. J. PischkeJ. L. Arnold M. J. RiceW. J. Bees B. F. ShelleyL. F. Campbell P. L. SturgillH. E. Gordon T. TaharaW. S. Jacobs K. Oyamada, DelegateD. J. Kreft R. Uebel, Delegate

Subgroup on General Requirements (BPV VIII)

S. C. Roberts, Chair C. C. NeelyD. B. DeMichael, Vice Chair A. S. OlivaresF. L. Richter, Secretary D. B. StewartR. J. Basile D. A. SwansonD. T. Davis K. K. TamJ. P. Glaspie A. H. Gibbs, DelegateL. E. Hayden, Jr. K. Oyamada, DelegateK. T. Lau R. Uebel, DelegateM. D. Lower

Subgroup on Heat Transfer Equipment (BPV VIII)

R. Mahadeen, Chair D. L. KurleT. W. Norton, Vice Chair B. J. LerchG. Aurioles S. MayeuxS. R. Babka U. R. MillerJ. H. Barbee R. J. StastnyO. A. Barsky K. Oyamada, DelegateI. G. Campbell F. Osweiller, CorrespondingA. Chaudouet MemberM. D. Clark S. Yokell, CorrespondingJ. I. Gordon MemberM. J. Holtz S. M. Caldwell, HonoraryF. E. Jehrio MemberG. G. Karcher

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Subgroup on High-Pressure Vessels (BPV VIII)

D. T. Peters, Chair S. C. MordreA. P. Maslowski, Staff E. A. Rodriguez

Secretary E. D. RollL. P. Antalffy J. R. Sims, Jr.R. C. Biel D. L. StangP. N. Chaku F. W. TatarR. Cordes S. TeradaR. D. Dixon R. WinkD. M. Fryer K. Oyamada, DelegateR. T. Hallman L. Fridlund, CorrespondingA. H. Honza MemberM. M. James M. D. Mann, ContributingP. Jansson MemberJ. A. Kapp G. J. Mraz, ContributingJ. Keltjens MemberD. P. Kendall D. J. Burns, Honorary MemberA. K. Khare E. H. Perez, Honorary

Member

Subgroup on Materials (BPV VIII)

J. F. Grubb, Chair K. Oyamada, DelegateJ. Cameron,Vice Chair E. E. Morgenegg,P. G. Wittenbach, Secretary Corresponding MemberA. Di Rienzo E. G. Nisbett, CorrespondingM. Gold MemberM. Katcher G. S. Dixit, ContributingW. M. Lundy MemberD. W. Rahoi J. A. McMaster, ContributingR. C. Sutherlin MemberE. Upitis

Subgroup on Toughness (BPV II & BPV VIII)

D. A. Swanson, Chair C. C. NeelyJ. L. Arnold M. D. RanaR. J. Basile F. L. RichterJ. Cameron J. P. Swezy, Jr.H. E. Gordon E. UpitisW. S. Jacobs J. VattappillyK. Mokhtarian K. Oyamada, Delegate

Special Working Group on Graphite Pressure Equipment(BPV VIII)

S. Malone, Chair R. W. DickersonE. Soltow, Vice Chair B. LukaschT. F. Bonn M. R. MinickF. L. Brown A. A. Stupica

Task Group on Impulsively Loaded Vessels (BPV VIII)

R. E. Nickell, Chair D. HildingG. A. Antaki K. W. KingJ. K. Asahina R. KitamuraD. D. Barker R. A. LeishearR. C. Biel P. LeslieD. W. Bowman F. OhlsonA. M. Clayton D. T. PetersJ. E. Didlake, Jr. E. A. RodriguezT. A. Duffey C. RomeroB. L. Haroldsen J. E. ShepherdH. L. Heaton



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COMMITTEE ON WELDING AND BRAZING (IX)

J. G. Feldstein, Chair M. J. PischkeW. J. Sperko, Vice Chair M. J. RiceS. J. Rossi, Staff Secretary M. B. SimsD. A. Bowers M. J. StankoR. K. Brown, Jr. J. P. Swezy, Jr.M. L. Carpenter P. L. Van FossonP. D. Flenner R. R. YoungR. M. Jessee S. Raghunathan, ContributingJ. S. Lee MemberW. M. Lundy S. D. Reynolds, Jr.,T. Melfi Contributing MemberW. F. Newell, Jr. W. D. Doty, HonoraryB. R. Newmark MemberA. S. Olivares

Subgroup on Brazing (BPV IX)

M. J. Pischke, Chair M. L. CarpenterE. W. Beckman A. F. GarbolevskyL. F. Campbell J. P. Swezy, Jr.

Subgroup on General Requirements (BPV IX)

B. R. Newmark, Chair H. B. PorterE. W. Beckman P. L. SturgillP. R. Evans K. R. WillensR. M. Jessee E. Molina, DelegateA. S. Olivares

Subgroup on Materials (BPV IX)

S. E. Gingrich C. E. SainzR. M. Jessee W. J. SperkoC. C. Kim M. J. StankoT. Melfi R. R. YoungS. D. Reynolds, Jr. V. Giunto, Delegate

Subgroup on Performance Qualification (BPV IX)

D. A. Bowers, Chair K. L. HayesV. A. Bell J. S. LeeL. P. Connor W. M. LundyR. B. Corbit E. G. ReicheltP. R. Evans M. B. SimsP. D. Flenner G. W. Spohn III

Subgroup on Procedure Qualification (BPV IX)

D. A. Bowers, Chair M. B. SimsM. J. Rice, Secretary W. J. SperkoM. Bernasek S. A. SpragueR. K. Brown, Jr. J. P. Swezy, Jr.J. R. McGimpsey P. L. Van FossonW. F. Newell, Jr. T. C. WiesnerA. S. Olivares E. Molina, DelegateS. D. Reynolds, Jr.

xxvi

COMMITTEE ONFIBER-REINFORCED PLASTIC PRESSURE VESSELS (X)

D. Eisberg, Chair D. L. KeelerP. J. Conlisk, Vice Chair B. M. LinnemannP. D. Stumpf, Staff Secretary N. L. NewhouseF. L. Brown D. J. PainterJ. L. Bustillos G. RamirezT. W. Cowley J. R. RichterI. L. Dinovo J. A. RolstonT. J. Fowler B. F. ShelleyM. R. Gorman F. W. Van NameD. H. Hodgkinson D. O. Yancey, Jr.L. E. Hunt P. H. Ziehl

COMMITTEE ONNUCLEAR INSERVICE INSPECTION (XI)

G. C. Park, Chair D. A. ScarthR. W. Swayne, Vice Chair F. J. Schaaf, Jr.R. L. Crane, Staff Secretary J. C. Spanner, Jr.W. H. Bamford, Jr. G. L. StevensC. B. Cantrell K. B. ThomasR. C. Cipolla E. W. Throckmorton IIIM. L. Coats D. E. WaskeyD. D. Davis R. A. WestR. L. Dyle C. J. WirtzE. L. Farrow R. A. YonekawaJ. Fletcher K. K. YoonE. B. Gerlach T. YuharaR. E. Gimple Y.-S. Chang, DelegateF. E. Gregor J. T. Lindberg, AlternateK. Hasegawa L. J. Chockie, HonoraryD. O. Henry MemberJ. C. Keenan C. D. Cowfer, HonoraryR. D. Kerr MemberS. D. Kulat O. F. Hedden, HonoraryG. L. Lagleder MemberD. W. Lamond L. R. Katz, Honorary MemberG. A. Lofthus P. C. Riccardella, HonoraryW. E. Norris MemberK. Rhyne

Executive Committee (BPV XI)

R. W. Swayne, Chair W. E. NorrisG. C. Park, Vice Chair K. RhyneR. L. Crane, Staff Secretary J. C. Spanner, Jr.W. H. Bamford, Jr. K. B. ThomasR. L. Dyle R. A. WestR. E. Gimple R. A. YonekawaJ. T. Lindberg

Subgroup on Evaluation Standards (SG-ES) (BPV XI)

W. H. Bamford, Jr., Chair K. KoyamaG. L. Stevens, Secretary D. R. LeeH.-D. Chung H. S. MehtaR. C. Cipolla J. G. MerkleG. H. DeBoo M. A. MitchellR. L. Dyle K. MiyazakiB. R. Ganta S. RanganathT. J. Griesbach D. A. ScarthK. Hasegawa T.-L. ShamK. Hojo K. R. WichmanD. N. Hopkins K. K. YoonY. Imamura Y.-S. Chang, Delegate



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Working Group on Flaw Evaluation (SG-ES) (BPV XI)

R. C. Cipolla, Chair H. S. MehtaG. H. DeBoo, Secretary J. G. MerkleW. H. Bamford, Jr. K. MiyazakiM. Basol R. K. QashuB. Bezensek S. RanganathJ. M. Bloom D. L. RudlandH.-D. Chung P. J. RushB. R. Ganta D. A. ScarthR. G. Gilada W. L. ServerT. J. Griesbach N. J. ShahH. L. Gustin T. V. VoF. D. Hayes K. R. WichmanP. H. Hoang G. M. WilkowskiK. Hojo S. X. XuD. N. Hopkins K. K. YoonK. Koyama V. A. ZilbersteinD. R. Lee

Working Group on Operating Plant Criteria (SG-ES) (BPV XI)

T. J. Griesbach, Chair M. A. MitchellW. H. Bamford, Jr. R. PaceH. Behnke S. RanganathB. A. Bishop W. L. ServerT. L. Dickson E. A. SiegelR. L. Dyle D. V. SommervilleS. R. Gosselin G. L. StevensM. Hayashi D. P. WeaklandH. S. Mehta K. K. Yoon

Working Group on Pipe Flaw Evaluation (SG-ES) (BPV XI)

D. A. Scarth, Chair K. HojoG. M. Wilkowski, Secretary D. N. HopkinsT. A. Bacon K. KashimaW. H. Bamford, Jr. R. O. McGillB. Bezensek H. S. MehtaH.-D. Chung K. MiyazakiR. C. Cipolla D. L. RudlandN. G. Cofie P. J. RushJ. M. Davis T.-L. ShamG. H. DeBoo T. V. VoB. Dogan B. S. WasilukB. R. Ganta S. X. XuL. F. Goyette K. K. YoonK. Hasegawa V. A. ZilbersteinP. H. Hoang

Subgroup on Nondestructive Examination (SG-NDE) (BPV XI)

J. C. Spanner, Jr., Chair D. O. HenryG. A. Lofthus, Secretary D. KurekC. A. Anderson G. L. LaglederT. L. Chan J. T. LindbergC. B. Cheezem G. R. PerkinsD. R. Cordes A. S. ReedF. E. Dohmen F. J. Schaaf, Jr.M. E. Gothard C. J. Wirtz

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Working Group on Personnel Qualification and SurfaceVisual and Eddy Current Examination (SG-NDE) (BPV XI)

A. S. Reed, Chair J. W. HoufD. R. Cordes, Secretary J. T. LindbergC. A. Anderson D. R. Quattlebaum, Jr.B. L. Curtis D. SpakeN. Farenbaugh J. C. Spanner, Jr.D. O. Henry M. C. WeatherlyK. M. Hoffman C. J. Wirtz

Working Group on Procedure Qualificationand Volumetric Examination (SG-NDE) (BPV XI)

M. E. Gothard, Chair R. A. KellerhallG. R. Perkins, Secretary D. KurekM. T. Anderson G. A. LofthusC. B. Cheezem C. E. MoyerA. D. Chockie S. A. SaboS. R. Doctor R. V. SwainF. E. Dohmen S. J. ToddK. J. Hacker

Subgroup on Repair/Replacement Activities (SG-RRA) (BPV XI)

R. A. Yonekawa, Chair J. C. KeenanE. V. Farrell, Jr., Secretary R. D. KerrS. B. Brown S. L. McCrackenR. E. Cantrell B. R. NewtonP. D. Fisher J. E. O’SullivanJ. M. Gamber R. R. StevensonE. B. Gerlach R. W. SwayneR. E. Gimple D. E. WaskeyD. R. Graham J. G. WeicksR. A. Hermann E. G. Reichelt, AlternateK. J. Karwoski

Working Group on Welding and Special Repair Processes(SG-RRA) (BPV XI)

D. E. Waskey, Chair M. LauD. J. Tilly, Secretary S. L. McCrackenR. E. Cantrell D. B. MeredithS. J. Findlan B. R. NewtonP. D. Fisher J. E. O’SullivanM. L. Hall G. R. PolingR. A. Hermann R. E. SmithK. J. Karwoski J. G. WeicksC. C. Kim K. R. Willens

Working Group on Design and Programs (SG-RRA) (BPV XI)

E. B. Gerlach, Chair D. R. GrahamS. B. Brown, Secretary G. F. HarttraftO. Bhatty T. E. HissJ. W. Collins M. A. PyneR. R. Croft R. R. StevensonG. G. Elder R. W. SwayneE. V. Farrell, Jr. A. H. TaufiqueS. K. Fisher T. P. Vassallo, Jr.J. M. Gamber R. A. Yonekawa



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Subgroup on Water-Cooled Systems (SG-WCS) (BPV XI)

K. B. Thomas, Chair S. D. KulatN. A. Palm, Secretary D. W. LamondJ. M. Agold A. McNeill IIIV. L. Armentrout T. NomuraJ. M. Boughman W. E. NorrisS. T. Chesworth G. C. ParkM. L. Coats J. E. StaffieraD. D. Davis E. W. Throckmorton IIIH. Q. Do R. A. WestE. L. Farrow G. E. WhitmanM. J. Ferlisi H. L. Graves III, AlternateO. F. Hedden

Working Group on Containment (SG-WCS) (BPV XI)

J. E. Staffiera, Chair H. L. Graves IIIH. M. Stephens, Jr., Secretary H. T. HillS. G. Brown R. D. HoughR. C. Cox C. N. KrishnaswamyJ. W. Crider D. J. NausM. J. Ferlisi F. Poteet IIIP. S. Ghosal G. ThomasD. H. Goche W. E. Norris, Alternate

Working Group on ISI Optimization (SG-WCS) (BPV XI)

D. R. Cordes, Chair A. H. MahindrakarS. A. Norman, Secretary S. A. SaboW. H. Bamford, Jr. S. R. ScottJ. M. Boughman E. A. SiegelJ. W. Collins K. B. ThomasM. E. Gothard G. E. WhitmanR. E. Hall Y. Yuguchi

Working Group on Implementation of Risk-Based Examination(SG-WCS) (BPV XI)

S. D. Kulat, Chair K. M. HoffmanS. T. Chesworth, Secretary A. T. KeimJ. M. Agold D. W. LamondB. A. Bishop J. T. LewisC. Cueto-Felgueroso R. K. MattuH. Q. Do A. McNeill IIIR. Fougerousse P. J. O’ReganM. R. Graybeal N. A. PalmJ. Hakii M. A. PyneK. W. Hall J. C. Younger

Working Group on Inspection of Systems and Components(SG-WCS) (BPV XI)

J. M. Agold, Chair S. D. KulatV. L. Armentrout, Secretary T. A. MeyerC. Cueto-Felgueroso D. G. NaujockH. Q. Do T. NomuraM. J. Ferlisi C. M. RossR. Fougerousse K. B. ThomasK. W. Hall G. E. Whitman

xxviii

Working Group on Pressure Testing (SG-WCS) (BPV XI)

D. W. Lamond, Chair R. E. HallJ. M. Boughman, Secretary A. McNeill IIIY.-K. Chung B. L. MontgomeryJ. J. Churchwell P. N. PassalugoT. Coste E. J. Sullivan, Jr.J. A. Doughty E. W. Throckmorton IIIG. L. Fechter IV

Special Working Group on Editing and Review (BPV XI)

R. W. Swayne, Chair J. E. StaffieraC. E. Moyer D. J. TillyK. R. Rao C. J. Wirtz

Special Working Group on Nuclear Plant Aging (BPV XI)

T. A. Meyer, Chair A. B. MeichlerD. V. Burgess, Secretary R. E. NickellS. Asada K. SakamotoY.-K. Chung W. L. ServerD. D. Davis R. L. TurnerF. E. Gregor G. G. YoungA. L. Hiser, Jr. G. E. Carpenter, Alternate

Special Working Group on High-Temperature Gas-CooledReactors (BPV XI)

J. Fletcher, Chair A. B. HullM. A. Lockwood, Secretary R. K. MillerN. Broom M. N. MitchellC. Cueto-Felgueroso T. RoneyK. N. Fleming F. J. Schaaf, Jr.S. R. Gosselin F. ShahrokhiM. R. Graybeal R. W. Swayne

Working Group on General Requirements (BPV XI)

K. Rhyne, Chair E. L. FarrowE. J. Maloney, Secretary J. C. KeenanG. P. Alexander R. K. MattuT. L. Chan S. R. ScottM. L. Coats G. E. Szabatura

COMMITTEE ON TRANSPORT TANKS (XII)

M. D. Rana, Chair M. D. PhamS. Staniszewski, Vice Chair M. PittsD. R. Sharp, Staff Secretary T. A. RogersA. N. Antoniou A. SelzC. H. Hochman W. K. SmithG. G. Karcher A. P. VargheseN. J. Paulick M. R. Ward

Subgroup on Design and Materials (BPV XII)

A. P. Varghese, Chair M. D. PhamR. C. Sallash, Secretary M. D. RanaP. Chilukuri T. A. RogersT. Hitchcock A. SelzG. G. Karcher M. R. WardS. L. McWilliams E. A. WhittleN. J. Paulick



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Subgroup on Fabrication and Inspection (BPV XII)

J. A. Byers D. J. KreftB. L. Gehl A. S. OlivaresL. D. Holsinger L. H. Strouse

Subgroup on General Requirements (BPV XII)

C. H. Hochman, Chair J. L. RademacherA. N. Antoniou, Secretary T. RummelT. W. Alexander R. C. SallashJ. L. Freiler W. K. SmithW. L. Garfield S. StaniszewskiK. L. Gilmore L. H. StrouseM. Pitts

Subgroup on Nonmandatory Appendices (BPV XII)

T. A. Rogers, Chair S. L. McWilliamsS. Staniszewski, Secretary M. PittsD. D. Brusewitz J. L. RademacherJ. L. Conley A. SelzT. Eubanks D. G. SheltonB. L. Gehl A. P. VargheseT. Hitchcock M. R. Ward

COMMITTEE ON BOILER ANDPRESSURE VESSEL CONFORMITY ASSESSMENT (CBPVCA)

W. C. LaRochelle, Chair D. C. Cook, AlternateP. D. Edwards, Vice Chair R. D. Danzy, AlternateK. I. Baron, Staff Secretary M. A. DeVries, AlternateW. J. Bees G. L. Hollinger, AlternateS. W. Cameron D. W. King, AlternateT. E. Hansen B. L. Krasiun, AlternateD. J. Jenkins P. F. Martin, AlternateK. T. Lau K. McPhie, AlternateL. E. McDonald G. P. Milley, AlternateK. M. McTague M. R. Minick, AlternateD. Miller T. W. Norton, AlternateB. R. Morelock F. J. Pavlovicz, AlternateJ. D. O’Leary M. T. Roby, AlternateT. M. Parks J. A. West, AlternateB. C. Turczynski R. V. Wielgoszinski, AlternateD. E. Tuttle A. J. Spencer, HonoraryE. A. Whittle MemberS. F. Harrison, Jr., Contributing

Member

xxix

COMMITTEE ON NUCLEAR CERTIFICATION (CNC)

R. R. Stevenson, Chair M. F. Sullivan, ContributingW. C. LaRochelle, Vice Chair MemberJ. Pang, Staff Secretary P. D. Edwards, AlternateM. N. Bressler D. P. Gobbi, AlternateG. Deily J. W. Highlands, AlternateS. M. Goodwin K. M. Hottle, AlternateK. A. Huber K. A. Kavanagh, AlternateM. Kotb B. G. Kovarik, AlternateJ. C. Krane B. L. Krasiun, AlternateR. P. McIntyre M. A. Lockwood, AlternateM. R. Minick R. J. Luymes, AlternateH. B. Prasse L. M. Plante, AlternateT. E. Quaka D. W. Stepp, AlternateD. M. Vickery E. A. Whittle, AlternateC. S. Withers H. L. Wiger, Alternate

COMMITTEE ONSAFETY VALVE REQUIREMENTS (BPV-SVR)

J. A. West, Chair S. F. Harrison, Jr.D. B. DeMichael, Vice Chair W. F. HartC. E. O’Brien, Staff Secretary D. MillerJ. F. Ball T. M. ParksS. Cammeresi D. K. ParrishJ. A. Cox T. PatelR. D. Danzy D. J. ScallanR. J. Doelling Z. WangJ. P. Glaspie

Subgroup on Design (BPV-SVR)

R. D. Danzy, Chair D. MillerC. E. Beair T. PatelJ. A. Conley T. R. TarbayR. J. Doelling J. A. West

Subgroup on General Requirements (BPV-SVR)

D. B. DeMichael, Chair J. W. RamseyJ. F. Ball J. W. RichardsonG. Brazier D. E. TuttleJ. P. Glaspie S. T. French, AlternateD. K. Parrish

Subgroup on Testing (BPV-SVR)

J. A. Cox, Chair W. F. HartJ. E. Britt B. K. NutterS. Cammeresi D. J. ScallanG. D. Goodson Z. Wang

U.S. Technical Advisory Group ISO/TC 185Safety Relief Valves

T. J. Bevilacqua, Chair D. B. DeMichaelC. E. O’Brien, Staff Secretary D. MillerJ. F. Ball B. K. NutterG. Brazier J. A. West



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PREAMBLE

This Code covers rules for construction of power boil-ers,1 electric boilers,2 miniature boilers,3 high-temperaturewater boilers,4 heat recovery steam generators,5 and certainfired pressure vessels6 to be used in stationary service andincludes those power boilers used in locomotive, portable,and traction service. Reference to a paragraph includes allthe subparagraphs and subdivisions under that paragraph.

The Code does not contain rules to cover all details ofdesign and construction. Where complete details are notgiven, it is intended that the manufacturer, subject to theacceptance of the Authorized Inspector, shall providedetails of design and construction which will be as safe asotherwise provided by the rules in the Code.

The scope of jurisdiction of Section I applies to theboiler proper and to the boiler external piping.

Superheaters, economizers, and other pressure parts con-nected directly to the boiler without intervening valvesshall be considered as parts of the boiler proper, and theirconstruction shall conform to Section I rules.

Boiler external piping shall be considered as that pipingwhich begins where the boiler proper or isolable super-heater, or isolable economizer terminates at:

(a) the first circumferential joint for welding end con-nections; or

(b) the face of the first flange in bolted flanged connec-tions; or

(c) the first threaded joint in that type of connection;and which extends up to and including the valve or valvesrequired by this Code.

ASME Code Certification (including Data Forms andCode Symbol Stamping), and/or inspection by the Author-ized Inspector, when required by this Code, is required forthe boiler proper and the boiler external piping.

1 Power boiler — a boiler in which steam or other vapor is generatedat a pressure of more than 15 psi (100 kPa) for use external to itself.

2 Electric boiler — a power boiler or a high-temperature water boilerin which the source of heat is electricity.

3 Miniature boiler — a power boiler or a high-temperature water boilerin which the limits specified in PMB-2 are not exceeded.

4 High-temperature water boiler — a water boiler intended for operationat pressures in excess of 160 psi (1.1 MPa) and/or temperatures in excessof 250°F (120°C).

5 Heat recovery steam generator (HRSG) — a boiler that has as itsprincipal source of thermal energy a hot gas stream having high-ramprates and temperatures such as the exhaust of a gas turbine.

6 Fired pressure vessel — reheaters, isolable superheaters, and noninte-gral separately fired superheaters.

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Construction rules for materials, design, fabrication,installation, and testing of the boiler external piping arecontained in ASME B31.1, Power Piping. Piping beyondthe valve or valves required by Section I is not within thescope of Section I, and it is not the intent that the CodeSymbol Stamp be applied to such piping or any otherpiping.

The material for forced-circulation boilers, boilers withno fixed steam and water line, and high-temperature waterboilers shall conform to the requirements of the Code. Allother requirements shall also be met except where theyrelate to special features of construction made necessaryin boilers of these types, and to accessories that are mani-festly not needed or used in connection with such boilers,such as water gages and water columns.

Reheaters receiving steam which has passed throughpart of a turbine or other prime mover and separately firedsteam superheaters which are not integral with the boilerare considered fired pressure vessels and their constructionshall comply with Code requirements for superheaters,including safety devices. Piping between the reheater con-nections and the turbine or other prime mover is not withinthe scope of the Code. Steam piping to the inlet connectionsand from the outlet connections of nonintegral separatelyfired superheaters is not within the scope of the Code.

A pressure vessel in which steam is generated by theapplication of heat resulting from the combustion of fuel(solid, liquid, or gaseous) shall be classed as a fired steamboiler.

Unfired pressure vessels in which steam is generatedshall be classed as unfired steam boilers with the followingexceptions:

(a) vessels known as evaporators or heat exchangers

(b) vessels in which steam is generated by the use ofheat resulting from operation of a processing system con-taining a number of pressure vessels such as used in themanufacture of chemical and petroleum products

Unfired steam boilers shall be constructed under theprovisions of Section I or Section VIII.

Expansion tanks connected to high-temperature waterboilers without intervening valves shall be constructed tothe requirements of Section I or Section VIII.

A pressure vessel in which an organic fluid is vaporizedby the application of heat resulting from the combustion



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of fuel (solid, liquid, or gaseous) shall be constructed underthe provisions of Section I. Vessels in which vapor isgenerated incidental to the operation of a processing sys-

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tem, containing a number of pressure vessels such as usedin chemical and petroleum manufacture, are not coveredby the rules of Section I.



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SUMMARY OF CHANGES

The 2010 Edition of this Code contains revisions in addition to the 2007 Edition with 2008 and 2009 Addenda.The revisions are identified with the designation (10) in the margin and, as described in the Foreword, becomemandatory 6 months after the publication date of the 2010 Edition. To invoke these revisions before theirmandatory date, use the designation “2010 Edition” in documentation required by this Code. If you choose notto invoke these revisions before their mandatory date, use the designation “2007 Edition through the 2009Addenda” in documentation required by this Code.

The Record Numbers listed below are explained in more detail in “List of Changes in Record Number Order”following this Summary of Changes.

Changes given below are identified on the pages by a margin note, (10), placed next to the affected area.

Page Location Change (Record Number)

xiii List of Sections (1) Paragraph below “Addenda” editorially revised(2) Second paragraph below “Interpretations” editorially

revised(3) Paragraph below “Code Cases” editorially revised

xv, xvi Foreword Ninth and eleventh paragraphs revised

xvii Statement of Policy (1) In the third paragraph, last sentence addedon the Use of (2) Last paragraph deletedCode Symbols

2 PG-5.1 Revised (09-19)

PG-5.6 Heading added (09-986)

PG-5.6.1 Redesignated from PG-5.6 and revised (09-986)

3 PG-5.6.2 Added (09-986)

PG-8.2.2 Revised (09-1125)

4, 5 PG-8.4.1.1 Designation editorially corrected

PG-8.4.1.2 Designation editorially corrected

PG-9.1 (1) SA/EN 10216-2 added (09-543)(2) SA/EN 10222-2 added (09-220)

PG-9.1.2 SB-167, SB-407, SB-423, SB-515, SB-516, and SB-517titles revised (09-1125)

PG-9.2 SB-167, SB-443, SB-444, SB-446, and SB-462 titlesrevised (09-1125)

9 PG-11.3.3 Revised (08-1013)

10, 11 PG-19 Sentence beginning with “Forming strains” undersubpara. (b) set as a new paragraph by errata (09-647)

PG-20 Added (08-1075)

12 Table PG-19 (1) Grades 230 and 617 added (09-17)(2) Grade 310HCbN added (09-349)

13 Table PG-20 Added (08-1075)

15 PG-27.1 First paragraph revised; fourth paragraph added (09-180)

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16 Table PG-26 (1) Steel group C-Mo added (09-778)(2) Notes (3) and (4) revised (09-181)(3) Notes (7) and (8) revised (09-778)

18, 19 PG-27.2.2 Heading revised (09-180)

PG-27.4 Designators added to notes for editorial purposes; cross-references updated

PG-27.4.9 First sentence revised (08-1013)

20–22 PG-29.1.1 Added (09-180)

PG-29.5 Revised (09-1411)

PG-29.7 Revised (09-1411)

PG-29.11 Last paragraph added (09-180)

PG-29.12 Revised (09-1411)

PG-29.13 Revised (09-1411)

24, 25 PG-31.4 Eighth, ninth, tenth, and sixteenth paragraphs revised(08-1013)

32 PG-38.1 Reference to PG-36.3 deleted from first sentence (09-785)

36, 37 PG-44.2 Revised (09-1569)

PG-47.1 Second sentence added (09-1608)

40, 41 PG-52.6 Last sentence revised (09-715)

PG-55.2 First sentence revised (08-1013)

43 Fig. PG-58.3.1(a) (1) Bold lines added by errata (09-1627)(2) “Main steam” callout corrected by errata (10-125)

44 Fig. PG-58.3.1(b) (1) Bold lines added by errata (09-1627)(2) PG-68.3 callout corrected by errata (09-1301)

45 Fig. PG-58.3.1(c) (1) Bold lines added by errata (09-1627)(2) Direction of arrow corrected by errata (09-1301)

46 Fig. PG-58.3.2 Bold lines added by errata (09-1627)

47 Fig. PG-58.3.3 Corrected by errata (09-1627)

54 PG-67.1 Spelling of “pressure” corrected by errata (09-1628)

PG-67.2.7 Added (09-1150)

58 PG-69.1.5 Spelling of “relief” corrected by errata (10-125)

PG-69.1.6 Spelling of “relief” corrected by errata (10-125)

62–70 PG-69.2.3 Last paragraph under subpara. (b) added (07-1148)

Table PG-69.2.3 Added (07-1148)

Table PG-69.2.3M Added (07-1148)

PG-73.2.1 Spelling of “at” corrected by errata (09-1628)

PG-73.2.11 Spelling of “relief” corrected by errata (10-125)

PG-73.4.3 Second and third sentences revised (09-229)

PG-73.5.1 Spelling of “following” corrected by errata (09-1628,10-125)

82 PG-110 Subparagraphs (e)(1) and (e)(2) revised (07-1148)

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84 PG-112.2.4 Added; subsequent paragraphs redesignated (08-171)

88 PW-11 Title revised (08-1013)

PW-11.1 Revised (08-1013)

PW-11.2 (1) First sentence revised (08-1013)(2) Definitions of RT and UT deleted (08-1013)(3) Definitions of nondestructive examination and

volumetric NDE added (08-1013)

89 Table PW-11 Revised in its entirety (08-1013)

90 PW-16.1 Reference to PW-16.7 added (08-1486)

PW-16.3 “Radiographic” revised to “volumetric” in secondsentence (08-1486)

96, 97 PW-16.7 Added (08-1486)

99 PW-28.5 Deleted (09-4)

100–112 PW-35.1 Penultimate sentence revised (08-1013)

PW-35.3 “Radiographic” revised to “volumetric” in first sentence(08-1486)

PW-39.1 Reference to Table PW-39.1 corrected to Table PW-39by errata (10-125)

Table PW-39 General Note (a)(15) added (08-1365)

Table PW-39 General Note (a)(10) added (08-1365)

Table PW-39 General Note (a)(8)(a) added; (b) and (c) redesignated(08-1365)

Table PW-39 General Note (d)(1) added; (2) and (3) redesignated(08-1365)

Table PW-39 General Note (b)(1) added; (2) and (3) redesignated(08-1365)

Table PW-39 Note (2) revised (09-1549)

Table PW-39 General Note (a)(1)(b)(2)(b) revised (08-1013)

Table PW-39 General Note (b)(1)(b)(2)(b) revised (08-1013)

PW-39.8 Revised (08-1365)

Table PW-39.1 Revised (09-726)

114 PW-43.1.1 Editorially revised

PW-43.1.2 Editorially revised

119 PW-51 Title revised (08-1013)

PW-51.1 Revised (08-1013)

PW-52 Title revised (08-1013)

PW-52.1 Revised (08-1013)

120 PW-52.3 Revised (08-1013)

134 PWT-12.2 Last sentence revised (08-1013)

135 PFT-11.3.6 Revised (08-1013)

136 PFT-11.4.6 Revised (08-1013)

xxxiv



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138 PFT-14.1 Last sentence revised (08-1013)

PFT-14.2 Revised (08-1013)

140 PFT-20.2.5 Revised (08-1013)

PFT-20.5.7 Revised (08-1013)

145 PFT-29 Last sentence revised (08-1013)

146, 147 PFT-32.1 Example editorially revised

PFT-40 Last sentence revised (08-1013)

PFT-45.1 Third sentence revised (08-1013)

153, 154 PMB-9 Revised (08-1013)

155 PMB-21.1.1 Title of SA-234 corrected by errata (10-125)

156 PEB-2.4 Revised (09-1407)

PEB-2.5 Added (07-1501)

157 PEB-9 Revised (08-1013)

165 I-2 Subparagraph (b) editorially revised

166 I-4 Last sentence editorially revised

169 Form III-1A Item 7 editorially revised

170 Guide Item 7 editorially revised

171–173 Mandatory Appendix Added (09-180)IV

195 A-70 Title deleted and inserted above A-71 (10-125)

196 A-71 Title deleted from A-70 and inserted above A-71 (10-125)

203 A-300 Designator editorially deleted

206, 207 A-302.4 Revised (09-19)


209 A-317.1 First sentence revised (09-180)

211 Form P-2 Item 8 editorially revised

213 A-351 Item 8 editorially revised

215, 217 Form P-2A (1) Item 8 editorially revised(2) New page 3 added (07-1501)

218 A-351.1 (1) Item 8 editorially revised(2) Item 34 revised (07-1501)(3) Items 37 and 38 added (07-1501)

220 Form P-2B Item 11 editorially revised

222 A-351.2 Item 11 editorially revised



229 Form P-3A Item 6 editorially revised



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236 Form P-4A Line 6 editorially revised

239 Form P-4B Line 6 editorially revised



244 Form P-7 Line 7 added (09-1150)

246 A-356 (1) Item 17 revised (09-1150)(2) Item 21 added (09-1150)

251 Table A-360 (1) Reference to ASME B16.5-2003 revised to readASME B16.5-2009 (09-1115)

(2) Note (4) added (09-57)

252 A-370 Item 3 revised (07-1501)



NOTE: Volume 60 of the Interpretations to Section I of the ASME Boiler and Pressure Vessel Code follows thelast page of this Edition.

xxxvi



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LIST OF CHANGES IN RECORD NUMBER ORDER

Record Number Change

07-201 Added rules to PG-20 for the heat treatment of 9Cr-2W (Grade 92) material, K92460, following cold work-ing.

07-1148 Revised PG-69.2.3, adding new requirements for pressures over 3,200 psig (22.1 MPa); added newTable PG-69.2.3; added text to PG-110(e)(2) and to A-356, Note (17).

07-1501 Revised Form P-2A, Manufacturer’s Data Report for All Types of Electric Boilers, to include Certificate ofField Assembly Compliance and Certificate of Field Assembly Inspection; revised A-370 “E” code symbolstamp, item 2, to read, “Design of electric boilers at the above location only and assembly of electric boilersat field sites controlled by the above location.”

08-171 Revised PG-112.2.3 to confirm that Form P-3A is not a partial data report.08-1013 Added definitions for NDE in PW-11.2. Changed title of Table PW-11 to state that it is for volumetric exam-

ination and modified notes accordingly. Referenced new mandatory appendix in Section V for UT require-ments for a Workmanship Based Acceptance Criteria. Changed references from radiographic examination tovolumetric examination throughout the Code where appropriate.

08-1075 Added new PG-20 to establish rules requiring post-forming heat treatment of certain creep strength enhancedferritic steels (only Grade 91 at this time) if certain cold-forming strain limits are exceeded.

08-1365 Revised PW-39.8 to include references to requirements in Table PW-39 and Table PW-39, P-Nos. 1, 3, 4,5A, and 5B to include references to PW-39.8.

08-1486 Added PW-16.7 to clarify fillet weld leg dimensions as they pertain to PW-16.09-4 Deleted text of PW-28.5 and replaced with “Deleted.”09-17 Added lines in PG-19 for UNS N06230 (Alloy 230) and UNS N06617 (Alloy 617).09-19 Revised PG-5.1 and A-302.4 to clarify the rules requiring the Manufacturer to ensure receipt of required

material certifications and that the material received is the correct material.09-57 Added Note (4) to Table A-360.09-180 Amended PG-27, PG-29, and A-317 and added new Mandatory Appendix IV to incorporate Code Cases

2330-1 and 2331-1.09-181 Revised Table PG-26, Note (3) to replace “Carbon steel pipes and tubes” with “Components made from car-

bon steel” and revised Note (4) to replace “pipe for” with “components made from.”09-220 Adopted ASME SA/EN 10222-2 in PG-9.1 to facilitate use of steel forgings of carbon, 1Cr-0.5Mo, 2.25Cr-

1Mo, and 9Cr-1Mo-V steel made to this specification.09-229 Revised PRD Certification Interval in PG-73.3 from 5 yr to 6 yr.09-349 Incorporated Code Case 2115-3 for austenitic stainless steel tubes, SA-213/SA-213M, Grade TP310HCbN,

UNS S31042, for Section I use, by adding the material to Table PG-19.09-543 Adopted seamless tubing European Specification EN 10216-2:2002 as SA/EN EN 10216-2:2002 into PG-9.1.09-715 Revised last sentence in PG-52.6 to clarify that pitch is determined at the mean radius of the cylinder.09-726 Deleted the metric values from Table PW-39.1 and changed the unit “hr/in. (min/mm)” into “hr”; added the

metric version of the unit thickness to Note (1).09-778 Revised Note (8) of PG-26 to clarify that Section I prohibits longitudinal seam welds in C-1⁄2Mo steel only at

temperatures above 850°F. Added a line to Table PG-26 to indicate a factor of 1.0 is used up to 850°F andinclude a reference to Note (8). Deleted the reference to Note (8) in the Cr-Mo line of the table.

09-875 Deleted reference to PG-36.3.09-986 Titled P-5.6 as P-No. 15E Group 1 Materials, and renumbered the first paragraph 5.6.1, with subparas. (a),

(b), and (c) following as in the original action. In addition, the first paragraph has been modified to makeclear that the 1470°F limiting temperature applies only when no weld is present in the heated area. Num-bered the final paragraph 5.6.2 and modified it to make clear that if a weld is present in an area heatedabove 1425°F after heat treatment, the rules of PW-39 apply.

09-1115 Revised Table A-360 to change the reference of B16.5-2003 to B16.5-2009.09-1125 Revised PG-8.2.2 to delete the title of SA-278. Revised PG-9.1.2 and PG-9.2 to add nickel-chromium-

cobalt-molybdenum alloy to the title of SB-167. Revised PG-9.2 to delete N06625 and replace it withnickel-chromium-molybdenum-columbium alloy in the title for SB-443, SB-444, and SB-446. RevisedPG-9.2 to add nickel to the title of SB-462.

09-1150 Added new PG-67.2.7, added new line number on P-7 data report, and added text as bullet 21 to A-356.09-1301 Changed PG-68.1 to PG-68.3 in Fig. PG-58.3.1(b).09-1407 Revised PEB-2.4 to add pipe immersion resistance heating elements.09-1411 Changed the words “diameter of shell” in PG-29.5, PG-29.7, PG-29.12, and PG-29.13 to “outside diameter

of the head.”

xxxvii



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Record Number Change

09-1549 Revised Table PW-39, P-No. 15E, Group 1, Note (2).09-1569 Revised PG-44.2 to permit handhole yokes to be made of cast iron.09-1608 Added requirement for sychronization of staybolt threads to PG-47.09-1667 Revised definition of “C” in Mandatory Appendix III.10-125 Corrected by errata.

xxxviii



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2010 SECTION I

PART PGGENERAL REQUIREMENTS FOR ALL

METHODS OF CONSTRUCTION

GENERAL

PG-1 SCOPE

The requirements of Part PG apply to power boilers andhigh pressure, high-temperature water boilers and to partsand appurtenances thereto and shall be used in conjunctionwith the specific requirements in the applicable Parts of thisSection that pertain to the methods of construction used.

PG-2 SERVICE LIMITATIONSPG-2.1 The rules of this Section are applicable to the

following services:(a) boilers in which steam or other vapor is generated

at a pressure of more than 15 psig (100 kPa) for use externalto itself

(b) high-temperature water boilers intended for opera-tion at pressures exceeding 160 psig (1.1 MPa) and/ortemperatures exceeding 250°F (120°C)

PG-2.2 For services below those specified in PG-2.1it is intended that rules of Section IV apply; however,boilers for such services may be constructed and stampedin accordance with this Section provided all applicablerequirements are met.

PG-2.3 Coil-type hot water boilers where the water canflash into steam when released directly to the atmospherethrough a manually operated nozzle may be exempted fromthe rules of this Section provided the following conditionsare met:

(a) There is no drum, header, or other steam space.(b) No steam is generated within the coil.(c) Tubing outside diameter does not exceed 1 in.

(25 mm).(d) Pipe size does not exceed NPS 3⁄4 (DN 20).(e) Nominal water capacity does not exceed 6 gal (23 L).(f) Water temperature does not exceed 350°F (175°C).(g) Adequate pressure relief valves and controls are pro-

vided.

1

PG-2.4 The rules of this Section are not intended toapply to thermal fluid heaters in which a fluid other thanwater is heated by the application of heat resulting fromthe combustion of solid, liquid, or gaseous fuel but inwhich no vaporization of the fluid takes place; however,such thermal fluid heaters may be constructed and stampedin accordance with this Section, provided all applicablerequirements are met.

PG-3 REFERENCED STANDARDS

Specific editions of standards referenced in this Sectionare shown in A-360.

PG-4 UNITS

Either U.S. Customary, SI, or any local customary unitsmay be used to demonstrate compliance with all require-ments of this edition (e.g., materials, design, fabrication,examination, inspection, testing, certification, and over-pressure protection).

In general, it is expected that a single system of unitsshall be used for all aspects of design except where unfeasi-ble or impractical. When components are manufactured atdifferent locations where local customary units are differentthan those used for the general design, the local unitsmay be used for the design and documentation of thatcomponent. Similarly, for proprietary components or thoseuniquely associated with a system of units different thanthat used for the general design, the alternate units may beused for the design and documentation of that component.

For any single equation, all variables shall be expressedin a single system of units. When separate equations areprovided for U.S. Customary and SI units, those equationsmust be executed using variables in the units associatedwith the specific equation. Data expressed in other unitsshall be converted to U.S. Customary or SI units for usein these equations. The result obtained from execution ofthese equations may be converted to other units.



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(10)

2010 SECTION I

Production, measurement and test equipment, drawings,welding procedure specifications, welding procedure andperformance qualifications, and other fabrication docu-ments may be in U.S. Customary, SI, or local customaryunits in accordance with the fabricator’s practice. Whenvalues shown in calculations and analysis, fabrication doc-uments or measurement and test equipment are in differentunits, any conversions necessary for verification of Codecompliance, and to ensure that dimensional consistency ismaintained, shall be in accordance with the following:

(a) Conversion factors shall be accurate to at least foursignificant figures.

(b) The results of conversions of units shall be expressedto a minimum of three significant figures.

Conversion of units, using the precision specified aboveshall be performed to ensure that dimensional consistencyis maintained. Conversion factors between U.S. Customaryand SI units may be found in A-390 of NonmandatoryAppendix A, Guidance for the Use of U.S. Customary andSI Units in the ASME Boiler and Pressure Vessel Code.Whenever local customary units are used, the Manufacturershall provide the source of the conversion factors whichshall be subject to verification and acceptance by theAuthorized Inspector or Certified Individual.

Material that has been manufactured and certified toeither the U.S. Customary or SI material specification (e.g.,SA-516M) may be used regardless of the unit system usedin design. Standard fittings (e.g., flanges, elbows, etc.) thathave been certified to either U.S. Customary or SI unitsmay be used regardless of the units system used in design.

All entries on a Manufacturer’s Data Report and datafor Code-required nameplate marking shall be in unitsconsistent with the fabrication drawings for the componentusing U.S. Customary, SI, or local customary units. It isacceptable to show alternate units parenthetically. Usersof this Code are cautioned that the receiving jurisdictionshould be contacted to ensure the units are acceptable.

MATERIALS

PG-5 GENERALPG-5.1 Except as otherwise permitted in PG-8.2,

PG-8.3, PG-10, and PG-11, material subject to stress dueto pressure shall conform to one of the specifications givenin Section II and shall be limited to those that are listedin the Tables of Section II, Part D. The manufacturer shallensure that the correct material has been received and isproperly identified before proceeding with construction(see A-302.4). Materials shall not be used at temperaturesabove those for which stress values are limited, for SectionI construction, in the Tables of Section II, Part D. Specificadditional requirements described in PG-5 through PG-13shall be met as applicable.

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PG-5.2 Material covered by specifications in SectionII is not restricted as to the method of production unlessso stated in the specification, and as long as the productcomplies with the requirements of the specification.

PG-5.3 If, in the development of the art of boiler con-struction, it is desired to use materials other than thoseherein described, data should be submitted to the Boilerand Pressure Vessel Committee in accordance with therequirements of Appendix 5 of Section II, Part D. Materialnot completely identified with any approved Code specifi-cations may be used in the construction of boilers underthe conditions outlined in PG-10.

PG-5.4 Size Limits and TolerancesPG-5.4.1 Materials outside the limits of size or thick-

ness given in the title or scope clause of any specificationin Section II may be used if the material is in compliancewith the other requirements of the specification, and nosimilar limitation is given in the rules for construction.

PG-5.4.2 Pipe having a tolerance of ±1% on eitherthe O.D. or the I.D., rather than the tolerance specified in thematerial specification, may be used, provided the materialcomplies with all other requirements of the specifications.When used under external pressure, such pipe shall belimited to a maximum of 24 in. (600 mm) in diameter.The pipe shall include the designation 1% O.D. or 1% I.D.,as appropriate, in any required documentation and markingof the material.

PG-5.5 The use of austenitic alloy steel is permittedfor boiler pressure parts that are steam touched in normaloperation. Except as specifically provided in PG-9.1.1,PG-12, and PEB-5.3, the use of such austenitic alloys forboiler pressure parts that are water wetted in normal serviceis prohibited.1

PG-5.6 P-No. 15E, Group 1 MaterialsPG-5.6.1 If during any phase of manufacturing or

erection any portion of the component that does not containa weld is heated to a temperature greater than 1,470°F(800°C), one of the following actions shall be performed:

(a) The component shall be reaustenitized and retem-pered in its entirety in accordance with the specificationrequirements.

(b) That portion of the component heated above 1,470°F(800°C), including the heat-affected zone created by the

1 Austenitic alloys are susceptible to intergranular corrosion and stresscorrosion cracking when used in boiler applications in water wettedservice. Factors that affect the sensitivity to these metallurgical phenom-ena are applied or residual stress and water chemistry. Susceptibility toattack is usually enhanced by using the material in a stressed conditionwith a concentration of corrosive agents (e.g., chlorides, caustic, orreduced sulfer species). For successful operation in water environments,residual and applied stresses must be minimized and careful attentionmust be paid to continuous control of water chemistry.

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local heating, must be replaced or must be removed, reaus-tenitized, and retempered in accordance with the specifica-tion requirements and then replaced in the component.

(c) If the allowable stress values to be used are lessthan or equal to those provided in Table 1A of Section II,Part D for Grade 9 (e.g., SA-213 T9, SA-335 P9, or equiva-lent product specifications) at the design temperature, thenthe requirements stated above may be waived, providedthat the portion of the component heated above 1,470°F(800°C) is retempered in accordance with the specificationrequirements. The use of this provision shall be noted onthe Manufacturer’s Data Report.

PG-5.6.2 If during any phase of manufacturing orerection of the component, any portion that does containa weld is heated above 1,425°F (775°C), then the require-ments of Notes (3) and (4) of Table PW-39 for P-No. 15E,Group 1 Materials, shall apply for reheat treatment.

PG-6 PLATEPG-6.1 Steel plates for any part of a boiler subject to

pressure, whether or not exposed to the fire or products ofcombustion, shall be of pressure vessel quality in accor-dance with one of the following specifications:

SA-202 Pressure Vessel Plates, Alloy Steel, Chromium-Manganese-Silicon

SA-204 Pressure Vessel Plates, Alloy Steel, Molyb-denum

SA-240 (Type 405 only) Pressure Vessel Plates, AlloySteel (Ferritic Stainless), Chromium

SA-285 Pressure Vessel Plates, Carbon Steel, Low-andIntermediate-Tensile Strength

SA-299 Pressure Vessel Plates, Carbon Steel, Manga-nese-Silicon

SA-302 Pressure Vessel Plates, Alloy Steel, Manganese-Molybdenum and Manganese-Molybdenum-Nickel

SA-387 Pressure Vessel Plates, Alloy Steel, Chromium-Molybdenum

SA-515 Pressure Vessel Plates, Carbon Steel, for Inter-mediate- and Higher-Temperature Service

SA-516 Pressure Vessel Plates, Carbon Steel, for Moder-ate- and Lower-Temperature Service

SA/AS 1548 Steel Plates for Pressure EquipmentSA/EN-10028-2 Flat Products Made of Steels for Pres-

sure PurposesSA/JIS G3118 Carbon Steel Plates for Pressure Vessels

for Intermediate and Moderate Temperature Service

PG-7 FORGINGSPG-7.1 Seamless steel drum forgings made in accor-

dance with SA-266 for Carbon-Steel and SA-336 for AlloySteel may be used for any part of a boiler for which pressurevessel quality is specified or permitted.

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PG-7.2 Forged flanges, fittings, nozzles, valves, andother pressure parts of the boiler shall be of material thatconforms to one of the forging specifications as listedin PG-9.

PG-7.3 Drums, shells, or domes may be of seamlessdrawn construction, with or without integral heads, pro-vided the material conforms to the requirements of theCode for shell material.

PG-8 CASTINGSPG-8.1 Except for the limited usage permitted by

PG-8.2 and PG-8.3, cast material used in the constructionof vessels and vessel parts shall conform to one of thespecifications listed in PG-9 for which maximum allowablestress values are given in Tables 1A and 1B of Section II,Part D. The allowable stress values shall be multiplied bythe applicable casting quality factor given in PG-25 for allcast materials except cast iron.

When cast iron is used as allowed in PG-11.1 for stan-dard pressure parts, it shall conform to one of these stan-dards

ASME B16.1, Cast Iron Pipe Flanges and Flanged Fit-tings

ASME B16.4, Cast Iron Threaded FittingsMaterial conforming to ASTM A 126 may be used sub-

ject to all requirements of the particular standard. Suchusage is subject also to all the requirements for the use ofcast iron given in PG-8.2 and other paragraphs of thisSection.

PG-8.2 Cast IronPG-8.2.1 Cast iron shall not be used for nozzles or

flanges attached directly to the boiler for any pressure ortemperature.

PG-8.2.2 Cast iron as designated in SA-278 may beused for boiler and superheater connections under pressure,such as pipe fittings, water columns, valves and their bon-nets, for pressures up to 250 psi (1.7 MPa), provided thesteam temperature does not exceed 450°F (230°C).

PG-8.3 Cast Nodular Iron. Cast nodular iron as desig-nated in SA-395 may be used for boiler and superheaterconnections under pressure, such as pipe fittings, watercolumns, and valves and their bonnets, for pressures notto exceed 350 psi (2.5 MPa), provided the steam tempera-ture does not exceed 450°F (230°C).

PG-8.4 Nonferrous. Bronze castings shall conform toSB-61, SB-62, and SB-148, and may be used only for thefollowing:

PG-8.4.1 For flanges and flanged or threaded fittingscomplying with the pressure and temperature requirementsof ASME B16.15 or B16.24, except that such fittings shallnot be used where steel or other material is specifically

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required. Threaded fittings shall not be used where flangedtypes are specified.

PG-8.4.1.1 For valves at allowable stress valuesnot to exceed those given in Table 1B of Section II, PartD, with maximum allowable temperatures of 550°F(290°C) for SB-61 and SB-148, and 406°F (208°C) forSB-62.

PG-8.4.1.2 For parts of pressure relief valves sub-ject to limitations of PG-67.7.

PG-9 PIPES, TUBES, AND PRESSURE-CONTAINING PARTS

Pipes, tubes, and pressure-containing parts used in boil-ers shall conform to one of the specifications listed in thisparagraph for which maximum allowable stresses are givenin Tables 1A and 1B of Section II, Part D. The stressvalues given in these tables include the applicable jointefficiency factor for welded pipes and tubes.

Open-hearth, electric furnace, or basic oxygen steel shallbe used for boiler pressure parts exposed to the fire orproducts of combustion. When used for internal pressure,the material stress and dimensions shall meet the appro-priate requirements of PG-27 and Part PW and be in accor-dance with the following:

PG-9.1 Boiler parts shall be of the following specifica-tions only:

SA-53 Welded and Seamless Steel Pipe (excluding gal-vanized)

SA-105 Forgings, Carbon Steel, for Piping ComponentsSA-106 Seamless Carbon Steel Pipe for High-Tempera-

ture ServiceSA-178 Electric-Resistance-Welded Carbon Steel Boiler

TubesSA-181 Forged or Rolled Steel Pipe Flanges, Forged

Fittings, and Valves and Parts for General ServiceSA-182 Forged or Rolled Alloy-Steel Pipe Flanges,

Forged Fittings, and Valves and Parts for High-Tempera-ture Service (ferritic only)

SA-192 Seamless Carbon Steel Boiler Tubes for HighPressure Service

SA-209 Seamless Carbon-Molybdenum Alloy-SteelBoiler and Superheater Tubes

SA-210 Seamless Medium Carbon Steel Boiler andSuperheater Tubes

SA-213 Seamless Ferritic and Austenitic Alloy-SteelBoiler, Superheater and Heat Exchanger Tubes (fer-ritic only)

SA-216 Carbon Steel Castings Suitable for Fusion Weld-ing for High-Temperature Service

SA-217 Alloy-Steel Castings for Pressure-ContainingParts Suitable for High-Temperature Service

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SA-234 Piping Fittings of Wrought Carbon Steel andAlloy Steel for Moderate and Elevated Temperatures

SA-250 Electric-Resistance-Welded Ferritic Alloy-SteelBoiler and Superheater Tubes

SA-266 Carbon Steel Seamless Drum ForgingsSA-268 Seamless and Welded Ferritic Stainless Steel

Tubing for General ServiceSA-333 Seamless and Welded Carbon and Alloy Steel

Pipe for Low-Temperature ServiceSA-335 Seamless Ferritic Alloy Steel Pipe for High-

Temperature ServiceSA-336 Alloy Steel Seamless Drum Forgings (ferritic

only)SA-423 Seamless and Electric Welded Low Alloy Steel

TubesSA-660 Centrifugally Cast Carbon Steel Pipe for High-

Temperature ServiceSA-731 Seamless, Welded Ferritic, and Martensitic

Stainless Steel PipeSA/EN 10216-2 Seamless Steel Tubes for Pressure Pur-

poses — Part 2: Technical Delivery Conditions for Non-Alloy and Alloy Steel Tubes With Specified ElevatedTemperature Properties

SA/EN 10222-2 Steel Forgings for Pressure Purposes —Part 2: Ferritic and Martensitic Steels With SpecifiedElevated Temperature Properties

PG-9.1.1 Boiler parts on once-through boilers shallbe any of the specifications listed in PG-9.1 or any of thefollowing:2

SB-407 Nickel-Iron-Chromium Alloy Seamless Pipeand Tube

SB-408 Nickel-Iron-Chromium Alloy Rod and BarSB-409 Nickel-Iron-Chromium Alloy Plate, Sheet, and

StripSB-423 Nickel-Iron-Chromium-Molybdenum Seamless

Pipe and TubeSB-424 Nickel-Iron-Chromium-Molybdenum-Copper

Alloy Plate, Sheet, and StripSB-425 Nickel-Iron-Chromium-Molybdenum-Copper

Alloy Rod and BarSB-515 Welded Nickel-Iron-Chromium Alloy TubesSB-564 Nickel Alloy Forgings

PG-9.1.2 Materials for use in connector piping ortubing and the pressure chamber for remote water level-sensing devices, as referenced in PG-12.2, shall be one ofthe specifications listed in PG-9.1 or one of the following:

SA-213 Seamless Ferritic, Austenitic, and Alloy SteelBoiler, Superheater, and Heat Exchanger Tubes

2 The maximum recommended feedwater-dissolved solids concentra-tion for once-through boilers is 0.050 ppm.

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SA-312 Seamless and Welded Austenitic StainlessSteel Pipe

SB-163 Seamless Nickel and Nickel Alloy Condenserand Heat Exchanger Tubes

SB-167 Nickel-Chromium-Iron Alloys and Nickel-Chro-mium-Cobalt Molybdenum Alloy Seamless Pipe andTube

SB-407 Nickel-Chromium-Iron Alloy Seamless Pipeand Tube

SB-423 Nickel-Iron-Chromium-Molybdenum SeamlessPipe and Tube

SB-515 Welded Nickel-Iron-Chromium Alloy TubesSB-516 Welded Nickel-Chromium-Iron Alloy TubesSB-517 Welded Nickel-Chromium-Iron Alloy PipeSB-619 Welded Nickel and Nickel-Cobalt Alloy PipeSB-622 Seamless Nickel and Nickel-Cobalt Alloy PipeSB-626 Welded Nickel and Nickel-Cobalt Alloy Tube

PG-9.2 Superheater parts shall be of any one of thespecifications listed in PG-9.1, PG-9.1.1, or one of thefollowing:

SA-182 Forged or Rolled Alloy-Steel Pipe Flanges,Forged Fittings, and Valves and Plates for High-Temper-ature Service

SA-213 Seamless Ferritic and Austenitic Alloy SteelBoiler, Superheater and Heat Exchanger Tubes

SA-240 Stainless and Heat-Resisting Chromium andChromium-Nickel Steel Plates, Sheet and Strip forFusion-Welded Unfired Pressure Vessels

SA-249 Welded Austenitic Steel Boiler, Superheater,Heat Exchanger, and Condenser Tubes

SA-312 Seamless and Welded Austenitic StainlessSteel Pipe

SA-351 Ferritic and Austenitic Steel Castings for High-Temperature Service

SA-369 Ferritic Alloy Steel Forged and Bored Pipe forHigh-Temperature Service

SA-376 Seamless Austenitic Steel Pipe for High-Tem-perature Central-Station Service

SA-479 Stainless and Heat-Resisting Steel Bars andShapes for Use in Boilers and Other Pressure Vessels

SA-965 Alloy Steel Seamless Drum ForgingsSA/JIS G 4303 Specification for Stainless Steel BarsSB-163 Seamless Nickel and Nickel Alloy Condenser

and Heat Exchanger TubesSB-166 Nickel-Chromium Iron Alloys and Nickel-

Chromium-Cobalt-Molybdenum Alloy Rod, Bar, andWire

SB-167 Nickel-Chromium Iron Alloys and Nickel-Chro-mium-Cobalt-Molybdenum Alloy Seamless Pipe andTube

SB-168 Nickel-Chromium Iron Alloys andNickel-Chromium-Cobalt-Molybdenum Alloy Plate,Sheet, and Strip

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SB-366 Factory-Made Wrought Nickel and Nickel AlloyFittings

SB-435 N06230 Plate, Sheet, and StripSB-443 Nickel-Chromium-Molybdenum-Columbium

Alloy Plate, Sheet, and StripSB-444 Nickel-Chromium-Molybdenum-Columbium

Alloy Pipe and TubeSB-446 Nickel-Chromium-Molybdenum-Columbium

Alloy Rod and BarSB-462 Forged or Rolled Nickel Alloy Pipe Flanges,

Forged Fittings, and Valves and Parts for Corrosive,High-Temperature Service

SB-511 Nickel-Iron-Chromium-Silicon Alloy Bars andShapes

SB-516 Welded Nickel-Chromium-Iron Alloy TubesSB-517 Welded Nickel-Chromium-Iron Alloy PipeSB-535 Nickel-Iron-Chromium-Silicon Alloys Seamless

Pipe and TubeSB-536 Nickel-Iron-Chromium-Silicon Alloys Plate,

Sheet, and StripSB-572 Nickel-Molybdenum-Chromium-Iron Alloy RodSB-574 Low-Carbon Nickel-Molybdenum-Chromium,

Low-Carbon Nickel-Chromium-Molybdenum, Low-Carbon Nickel-Molybdenum-Chromium-Tantalum,Low-Carbon Nickel-Chromium-Molybdenum-Copper,and Low-Carbon Nickel-Chromium-Molybdenum-Tungsten Alloy Rod

SB-575 Low-Carbon Nickel-Molybdenum-Chromium,Low-Carbon Nickel-Chromium-Molybdenum, Low-Carbon Nickel-Chromium-Molybdenum-Copper, Low-Carbon Nickel-Chromium-Molybdenum-Tantalum, andLow-Carbon Nickel-Chromium-Molybdenum-TungstenAlloy Plate, Sheet, and Strip

SB-619 Welded Nickel and Nickel-Cobalt Alloy PipeSB-622 Seamless Nickel and Nickel-Cobalt Alloy Pipe

and TubeSB-626 Welded Nickel and Nickel-Cobalt Alloy Tube

PG-9.3 Copper or copper alloy pipe or tubes shall notbe used in the boiler proper for any service where thetemperature exceeds 406°F (208°C). Copper and copperalloys shall be seamless, having a thickness not less thanASME Schedule 40 standard pipe, and shall comply toone of the following specifications: SB-42, Seamless Cop-per Pipe, Standard Sizes; SB-43, Seamless Red Brass Pipe,Standard Sizes; SB-75, Seamless Copper Tube; or SB-111,Copper and Copper-Alloy Seamless Condenser Tubes andFerrule Stock.

PG-9.4 Bimetallic tubes, having a core of an acceptableboiler and superheater material, and having an externalcladding of another metal alloy, may be used provided therequirements of PG-27.2.1.5 are met. In applying the rulesof PG-27.2.1, tubes that are diffusion coated shall not be



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permitted to include the strength of the clad. The permissi-ble variation in wall thickness tolerance of SA-450 orSB-163, as applicable, shall apply to the total wall thick-ness. The thickness and over and undertolerances of thecladding shall be included in the ordering information.Marking of the bimetallic tubular product shall meet thespecification requirements of the core material, but shallalso suitably identify the cladding alloy.

PG-9.5 ERW products shall be limited to a maximumthickness of 1⁄2 in. (13 mm) for internal pressure applica-tions. For external pressure applications, ERW productsshall be limited to a maximum thickness of 1⁄2 in. (13 mm)and a maximum size of NPS 24 (DN 600). The thicknessand diameter limitations noted above shall be within toler-ances stated by the product material specification.

PG-9.6 In addition to other materials permitted by thisSection, instrument wells may be fabricated from one ofthe following titanium alloys:

(a) SB-265, titanium and titanium alloy strip, sheet,and plate

(b) SB-338, seamless and welded titanium and titaniumalloy tubes for condensers and heat exchangers

(c) SB-348, titanium and titanium alloy bars and billets(d) SB-861, titanium and titanium alloy seamless pipe(e) SB-862, titanium and titanium alloy welded pipe

PG-9.7 In addition to other materials permitted by thisSection, the following materials are permitted only for usein economizers or feedwater heaters and associated piping:

(a) SA-182, Forged or Rolled Alloy-Steel Pipe Flanges,Forged Fittings, and Valves and Parts for High-Tempera-ture Pressure Service (S31803 only)

(b) SA-240, Pressure Vessel Plate, Alloy Steel (FerriticStainless), Chromium (S31803 only)

(c) SA-479, Stainless Steel Bars and Shapes (S31803only)

(d) SA-789, Seamless and Welded Ferritic AusteniticStainless Steel Tubing (S31803 only)

(e) SA-790, Seamless and Welded Ferritic AusteniticStainless Steel Pipe (S31803 only)

(f) SA-815, Wrought Ferritic, Ferritic Austenitic, andMartensitic Stainless Steel Piping Fittings (S31803 only)

PG-10 MATERIAL IDENTIFIED WITH ORPRODUCED TO A SPECIFICATIONNOT PERMITTED BY THISSECTION, AND MATERIAL NOTFULLY IDENTIFIED

PG-10.1 Identified With Complete CertificationFrom the Material Manufacturer. Material identifiedwith a specification not permitted by this Section, or mate-rial procured to chemical composition requirements and

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identified to a single production lot as required by a permit-ted specification may be accepted as satisfying the require-ments of a specification permitted by this Section providedthe conditions set forth in PG-10.1.1 or PG-10.1.2 aresatisfied.

PG-10.1.1 Recertification by an organization otherthan the boiler or part manufacturer:

PG-10.1.1.1 All requirements, including but notlimited to, melting method, melting practice, deoxidation,quality, and heat treatment, of the specification permittedby this Section, to which the material is to be recertified,have been demonstrated to have been met.

PG-10.1.1.2 A copy of the certification by thematerial manufacturer of the chemical analysis requiredby the permitted specification, with documentation show-ing the requirements to which the material was producedand purchased, and which demonstrates that there is noconflict with the requirements of the permitted specifica-tion, has been furnished to the boiler or part manufacturer.

PG-10.1.1.3 A certification that the material wasmanufactured and tested in accordance with the require-ments of the specification to which the material is recerti-fied, excluding the specific marking requirements, has beenfurnished to the boiler or part manufacturer, together withcopies of all documents and test reports pertinent to thedemonstration of conformance to the requirements of thepermitted specification.

PG-10.1.1.4 The material, and the Certificate ofCompliance or the Material Test Report have been identi-fied with the designation of the specification to which thematerial is recertified and with the notation “Certified perPG-10.”

PG-10.1.2 Recertification by the boiler or part manu-facturer.

PG-10.1.2.1 A copy of the certification by thematerial manufacturer of the chemical analysis requiredby the permitted specification, with documentation show-ing the requirements to which the material was producedand purchased, which demonstrates that there is no conflictwith the requirements of the permitted specification, isavailable to the Inspector.

PG-10.1.2.2 For applications in which the maxi-mum allowable stresses are subject to a note of Table 1Aof Section II, Part D, requiring the use of killed steel,documentation is available to the Inspector that establishesthat the material is a killed steel.

PG-10.1.2.3 Documentation is available to theInspector that demonstrates that the metallurgical structure,mechanical property, and hardness requirements of thepermitted specification have been met.

PG-10.1.2.4 For material recertified to a permittedspecification that requires a fine austenitic grain size or that



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requires that a fine grain practice be used during melting,documentation is available to the Inspector that demon-strates that the heat treatment requirements of the permittedspecification have been met, or will be met during fabri-cation.

PG-10.1.2.5 The material has marking, acceptableto the Inspector, for identification to the documentation.

PG-10.1.2.6 When the conformance of the mate-rial with the permitted specification has been established,the material has been marked as required by the permittedspecification.

PG-10.2 Material Identified to a Particular Produc-tion Lot as Required by a Specification Permitted byThis Section but That Cannot Be Qualified UnderPG-10.1. Any material identified to a particular productionlot as required by a specification permitted by this Section,but for which the documentation required in PG-10.1 is notavailable, may be accepted as satisfying the requirements ofthe specification permitted by this Section provided thatthe conditions set forth below are satisfied.

PG-10.2.1 Recertification by an organization otherthan the boiler or part manufacturer — not permitted.

PG-10.2.2 Recertification by the boiler or part manu-facturer.

PG-10.2.2.1 Chemical analyses are made on dif-ferent pieces from the lot to establish a mean analysiswhich is to be accepted as representative of the lot. Thepieces chosen for analyses shall be selected at randomfrom the lot. The number of pieces selected shall be atleast 10% of the number of pieces in the lot, but not lessthan three. For lots of three pieces or less, each pieceshall be analyzed. Each individual analysis in the permittedspecification and the mean for each element shall conformto the heat analysis limits of that specification. Analysesneed to be made for only those elements required by thepermitted specification. However, consideration should begiven to making analyses for elements not specified in thespecification but which would be deleterious if present inexcessive amounts.

PG-10.2.2.2 Mechanical property tests are madein accordance with the requirements of the permitted speci-fication and the results of the tests conform to the specifiedrequirements.

PG-10.2.2.3 For applications in which the maxi-mum allowable stresses are subject to a note of Table 1Aof Section II, Part D, requiring the use of killed steel,documentation is available to the Inspector which estab-lishes that the material is a killed steel.

PG-10.2.2.4 When the requirements of the permit-ted specification include metallurgical structure require-ments (i.e., fine austenitic grain size), tests are made and

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the results are sufficient to establish that those requirementsof the specification have been met.

PG-10.2.2.5 When the requirements of the permit-ted specification include heat treatment, the material is heattreated in accordance with those requirements, either priorto or during fabrication.

PG-10.2.2.6 When the conformance of the mate-rial with the permitted specification has been established,the material has been marked as required by the permittedspecification.

PG-10.3 Material Not Fully Identified. Materialwhich cannot be qualified under the provisions of eitherPG-10.1 or PG-10.2, such as material not fully identifiedas required by the permitted specification or as unidentifiedmaterial, may be accepted as satisfying the requirementsof a specification permitted by this Section provided thatthe conditions set forth below are satisfied.

PG-10.3.1 Qualification by an organization otherthan the boiler or part manufacturer — not permitted.

PG-10.3.2 Qualification by the boiler or part manu-facturer.

PG-10.3.2.1 Each piece is tested to show that itmeets the chemical composition for product analysis andthe mechanical properties requirements of the permittedspecification. Chemical analyses need only be made forthose elements required by the permitted specification.However, consideration shall be given to making analysesfor elements not specified in the specification but whichwould be deleterious if present in excessive amounts. Forplates, when the direction of final rolling is not known,both a transverse and a longitudinal tension test specimenshall be taken from each sampling location designated inthe permitted specification. The results of both tests shallconform to the minimum requirements of the specification,but the tensile strength of only one of the two specimensneed conform to the maximum requirement.

PG-10.3.2.2 The provisions of PG-10.2.2.3,PG-10.2.2.4, and PG-10.2.2.5 are met.

PG-10.3.2.3 When the identity of the materialwith the permitted specification has been established inaccordance with PG-10.3.2.1 and PG-10.3.2.2, each piece(or bundle, etc., if permitted in the specification) is markedwith a marking giving the permitted specification numberand grade, type, or class as applicable and a serial numberidentifying the particular lot of material. A suitable report,clearly marked as being a “Report on Tests of NonidentifiedMaterial,” shall be completed and certified by the boileror part manufacturer. This report, when accepted by theInspector, shall constitute authority to use the material inlieu of material procured to the requirements of the permit-ted specification.



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PG-11 MISCELLANEOUS PRESSURE PARTS

Prefabricated or preformed pressure parts for boilerswhich are subject to allowable working stresses due tointernal or external pressure in the boiler and which arefurnished by other than the shop of the Manufacturerresponsible for the completed boiler shall conform to allapplicable requirements of the Code for the completedboiler, including inspection in the shop of the parts manu-facturer and the furnishing of Manufacturer’s Partial DataReports as provided for in PG-112.2.4 except as permittedin PG-11.1, PG-11.2, and PG-11.3.

PG-11.1 Cast, Forged, Rolled, or Die-Formed Stan-dard Pressure Parts

PG-11.1.1 Pressure parts such as pipe fittings,valves, flanges, nozzles, welding necks, welding caps, man-hole frames and covers, and casings of pumps that are partof a boiler circulating system that are wholly formed bycasting, forging, rolling, or die forming shall not requireinspection, mill test reports, or Partial Data Reports. Stan-dard pressure parts that comply with some ASME Stan-dard3 shall be made of materials permitted by this Sectionor of materials specifically listed in an ASME productstandard listed elsewhere in this Section but not of materialsspecifically prohibited or beyond use limitations listed inthis Section. Standard pressure parts that comply with amanufacturer’s standard4,5 shall be made of materials per-mitted by this Section. Such parts shall be marked withthe name or trademark of the parts manufacturer and suchother markings as are required by the standard. Such mark-ings shall be considered as the parts manufacturer’s certifi-cation that the product complies with the materialspecifications and standards indicated and is suitable forservice at the rating indicated. The intent of the paragraphwill have been met if, in lieu of the detailed marking onthe part itself, the parts described herein have been markedin any permanent or temporary manner that will serve toidentify the part with the parts manufacturer’s written list-ing of the particular items and such listings are availablefor examination by the Inspector.

PG-11.1.2 Parts of small size falling within this cate-gory for which it is difficult or impossible to obtain identi-fied material or that may be stocked and for which milltest reports or certificates cannot be economically obtained

3 These are pressure parts that comply with some ASME productstandard accepted by reference in PG-42. The ASME product standardestablishes the basis for the pressure–temperature rating and marking.

4 These are pressure parts that comply with a parts manufacturer’sstandard that defines the pressure–temperature rating marked on the partand described in the parts manufacturer’s literature. The Manufacturerof the completed vessel shall satisfy himself that the part is suitable forthe design conditions of the completed vessel.

5 Pressure parts may be in accordance with an ASME product standardnot covered by footnote 4, but such parts shall satisfy the requirementsapplicable to a parts manufacturer’s standard and footnote 6.

8

and are not customarily furnished, and that do not apprecia-bly affect the safety of the vessel, may be used for relativelyunimportant part or parts stressed to not more than 50%of the stress value permitted by this Section, and listed inTables 1A and 1B of Section II, Part D, provided they aresuitable for the purpose intended and meet the approvalof the Inspector. The Manufacturer of the completed vesselshall satisfy himself that the part is suitable for the designconditions specified for the completed vessel.

PG-11.2 Cast, Forged, Rolled, or Die-Formed Non-standard Pressure Parts. Pressure parts such as shells,heads, removable and access opening cover plates, that arewholly formed by casting, forging, rolling, or die forming,may be supplied basically as materials. All such parts shallbe made of materials permitted under this Section, and themanufacturer of the part shall furnish mill test reports orother acceptable evidence to that effect. Such parts shallbe marked with the name or trademark of the parts manu-facturer and with such other markings as will serve toidentify the particular parts with accompanying materialidentification. The Manufacturer of the completed boilershall satisfy himself that the part is suitable for the designconditions specified for the completed boiler.

PG-11.3 Welded Standard Pressure Parts for UseOther Than the Shell of a Vessel.6 Pressure parts suchas welded standard pipe fittings, caps, valves, and flangesthat are fabricated by one of the welding processes recog-nized by this Section shall not require inspection, mill testreports, or Manufacturers’ Partial Data Reports provided.7

PG-11.3.1 Standard pressure parts that comply withsome ASME product standard4 shall be made of materialspermitted by this Section or of materials specifically listedin an ASME product standard accepted and listed elsewherein this Section but not of materials specifically prohibitedor beyond use limitations listed in this Section. Standardpressure parts that comply with a manufacturer’s stan-dard4,5 shall be made of materials permitted by this Section.

PG-11.3.2 Welding for pressure parts that complywith a manufacturer’s standard4,5 shall comply with therequirements of PW-26 through PW-39. Welding for pres-sure parts that comply with some ASME product standard3

shall comply with the requirements of PW-26 throughPW-39 or, as a minimum, may comply with the weldingrequirements of SA-234. Markings where applicable, orcertification by the parts manufacturer where markings arenot applicable shall be accepted as evidence of compliancewith the above welding requirements. Such parts shall bemarked as required by PG-11.1.1.

6 Fusion-welded pipe, with added filler metal, for use as the shell ofthe vessel shall be subject to the same requirements as a shell fabricatedfrom plate, including inspection at the point of manufacture and Manufac-turers’ Partial Data Reports.

7 For requirements for welded water columns, see PW-42.



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2010 SECTION I

PG-11.3.3 If volumetric examination or heat treat-ment is required by the applicable rules of this Section, itmay be performed either in the plant of the parts manufac-turer or in the plant of the Manufacturer of the completedvessel.

If the volumetric examination is done under the controlof the parts manufacturer, the reports shall be forwardedto the vessel manufacturer. Whenever radiography is used,a properly identified set of radiographs shall also be for-warded. All examination reports and radiographs shall beavailable to the Authorized Inspector.

PG-11.3.4 If heat treatment is performed at the plantof the parts manufacturer, certification by the parts manu-facturer that such treatment was performed shall beaccepted as evidence of compliance with applicable Codeparagraphs. This certification shall be available to theAuthorized Inspector. The Manufacturer of the completedvessel shall satisfy himself that the part is suitable for thedesign conditions specified for the completed vessel.

PG-12 WATER LEVEL INDICATORS ANDCONNECTOR MATERIAL

PG-12.1 Gage glass body and connector materials shallcomply with a Manufacturer’s standard that defines thepressure–temperature rating marked on the unit. The mate-rials used may include austenitic stainless steels and nickel-based alloys (see PG-5.5, footnote 1).

PG-12.2 Boilers having a maximum allowable workingpressure not exceeding 900 psi (6 MPa) may use alternativemethods for independent remote water level indicators orwater level-sensing devices (see PG-60 for requirementsfor water level indicators and water columns). The sensingdevices may include a magnetically coupled float inside anonmagnetic cylindrical pressure chamber to utilizethrough-the-wall sensing of float position. The pressurechamber stresses and dimensions shall meet the appropriaterequirements of PG-27 and Part PW, shall comply withone of the specifications in PG-9.1.2, and shall be restrictedto the material grades listed in PG-12.3.

PG-12.3 Connector material and the pressure chambermaterial of the remote water level indicator or water level-sensing devices, except for water columns, may includeaustenitic stainless steels and nickel-based alloys. Thematerial shall be in the solution-annealed heat treatmentcondition. If filler metals are used in welding of the austen-itic stainless steels, they shall be limited to low-carboncontent.

The material shall be one of the grades from the follow-ing list:

9

Grade UNS Number

304L S30403316L S31603800 N0880020-Cb3 N08020825 N08825C-276 N10276C-22 N06022690 N0669059 N06059625 N06625600 N06600

The allowable stresses shall be those listed in SectionII, Part D, Table 1A or 1B for Section I. If allowablestresses are not listed for Section I but are listed for SectionVIII, Div. 1, the allowable stresses for Section VIII, Div.1 may be utilized. When two lines of stresses are listed inSection II, Part D, the design shall be based on the lowerallowable stresses.

PG-13 STAYS

Threaded stays shall be of steel complying with SA-36or SA-675.

Seamless steel tubes for threaded stays shall complywith SA-192 or SA-210.

Staybolts, stays, through-rods, or stays with ends forattachment by fusion welding shall comply with SA-36 orSA-675.

PG-14 RIVETS

PG-14.1 Rivets shall conform to SA-31, Specificationfor Steel Rivets and Bars for Rivets, Pressure Vessels.

PG-14.1.1 In lieu of SA-31, it is permissible to sub-stitute bar which is converted to rivets from SA-36, Speci-fication for Carbon Structure Steel, under the conditionsspecified in PG-14.1.1.1 and PG-14.1.1.2.

PG-14.1.1.1 In addition to compliance with SA-36, the bar shall comply with

(a) the “rivet bend tests” for SA-31 Grade B, para. 6.1.2(b) the “rivet flattening tests” for SA-31 Grades A and

B, para. 6.2(c) the “bar bend tests” for SA-31 Grade B, para. 6.4.2

PG-14.1.1.2 The following paragraphs of SA-31shall be applicable to the additional mechanical proper-ties tests:

(a) paragraph 9, Number of Tests and Retests(b) paragraph 10, Specimen Preparation(c) paragraph 11, Test Methods(d) paragraph 12, Inspection(e) paragraph 13, Rejection and Reheating



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2010 SECTION I

PG-14.1.2 When rivets made from SA-36 bar aresubstituted for those made from SA-31, the design stressesfor SA-31 Grade B shall apply.

PG-14.2 In computing the ultimate strength of rivetsin shear, the following shear stresses in ksi (MPa) of thecross-sectional area of the rivet shank shall be used:

(a) Steel rivets, SA-31 Grade A, in single shear, 44.0(305)

(b) Steel rivets, SA-31 Grade A, in double shear,88.0 (605)

(c) Steel rivets, SA-31 Grade B, in single shear, 52.0(360)

(d) Steel rivets, SA-31 Grade B, in double shear,104.0 (715)

The cross-sectional area used in the computations shallbe that of the rivet after driving.

DESIGN

PG-16 GENERALPG-16.1 The design of power boilers, high-temperature

water boilers, and other pressure parts included within thescope of these rules shall conform to the general designrequirements in the following paragraphs and in addition tothe specific requirements for design given in the applicableParts of this Section that pertain to the methods of construc-tion used. This Section does not contain rules to cover allpossible details of design. When detailed rules are notgiven, it is intended that the Manufacturer, subject to theacceptance of the Inspector, shall provide details of designthat will be as safe as those provided by the rules ofthis Section. This may be done by appropriate analyticalmethods, the appropriate use of rules from other designcodes or, as permitted by PG-18, by proof test.

PG-16.2 When the pressure parts of a forced-flowsteam generator with no fixed steam and waterline aredesigned for different pressure levels as permitted inPG-21.2, the owner shall provide or cause to be provideda boiler pressure system design diagram, certified by aProfessional Engineer experienced in the mechanicaldesign of power plants, which supplies the following infor-mation.

PG-16.2.1 The relative location of the various pres-sure parts within the scope of Section I, with respect tothe path of water-steam flow.

PG-16.2.2 A line showing the expected maximumsustained pressure as described in PG-21.2, indicating theexpected variation in pressure along the path of water-steam flow.

PG-16.2.3 The maximum allowable working pres-sure of the various pressure parts.

10

PG-16.2.4 The location and set pressure of the over-pressure protection devices.

Copy of this diagram shall be attached to the MasterData Report per PG-113.

PG-16.3 Minimum Thicknesses. The minimum thick-ness of any boiler plate under pressure shall be 1⁄4 in. (6 mm)except for electric boilers constructed under the rules ofPart PEB. The minimum thickness of plates to which staysmay be applied in other than cylindrical outer shell platesshall be 5⁄16 in. (8 mm). When pipe over NPS 5 (DN 125)is used in lieu of plate for the shell of cylindrical compo-nents under pressure, its minimum wall shall be 1⁄4 in.(6 mm).

PG-16.4 Undertolerance on Plates. Plate material thatis not more than 0.01 in. (0.3 mm) thinner than that calcu-lated from the formula may be used in Code constructionsprovided the material specification permits such plate tobe furnished not more than 0.01 in. (0.3 mm) thinner thanordered.

PG-16.5 Undertolerance on Pipe and Tubes. Pipe ortube material shall not be ordered thinner than that calcu-lated from the applicable formula of this Section. Theordered material shall include provision for the allowedmanufacturing undertolerance as given in Section II in theapplicable pipe or tube specification.

PG-17 FABRICATION BY A COMBINATIONOF METHODS

A boiler and parts thereof may be designed and fabri-cated by a combination of the methods of fabrication givenin this Section, provided the rules applying to the respectivemethods of fabrication are followed and the boiler is limitedto the service permitted by the method of fabrication havingthe most restrictive requirements.

PG-18 DESIGN VALIDATION BY PROOFTEST

Where no rules are given for calculating the strength ofa boiler or any part thereof, the Manufacturer may establishMAWP by testing a full-size sample in accordance with A-22, Proof Test to Establish Maximum Allowable WorkingPressure.

PG-19 COLD FORMING OF AUSTENITICMATERIALS8

The cold-formed areas of pressure-retaining componentsmanufactured of austenitic alloys shall be heat treated for

8 See Section II, Part D, Appendix A, para. A-370, for background onthe rules in PG-19.

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2010 SECTION I

20 min per inch of thickness or for 10 min, whichever isgreater, at the temperatures given in Table PG-19 underthe following conditions:

(a) the finishing-forming temperature is below the mini-mum heat-treating temperature given in Table PG-19

(b) the design metal temperature and the forming strainsexceed the limits shown in Table PG-19.

Forming strains shall be calculated as follows:(1) Cylinders formed from plate

%Strain p50tRf �1 −

Rf

Ro �(2) Spherical or dished heads formed from plate

%Strain p75tRf �1 −

Rf

Ro �(3) Tube and pipe bends

%Strain p100r

R

where

R p nominal bending radius to centerline of pipe ortube

Rf p mean radius after formingRo p original mean radius (equal to infinity for a flat

plate)r p nominal outside radius of pipe or tubet p nominal thickness of the plate, pipe, or tube before

forming

PG-19.1 When the forming strains cannot be calculatedas shown in PG-19, the manufacturer shall have the respon-sibility to determine the maximum forming strain.

PG-19.2 For flares, swages, or upsets, heat treatmentin accordance with Table PG-19 shall apply, regardless ofthe amount of strain.

PG-20 COLD FORMING OF CREEPSTRENGTH ENHANCED FERRITICSTEELS

The cold-formed areas of pressure-retaining componentsmanufactured of creep strength enhanced ferritic alloysshall be heat treated as listed in Table PG-20. Cold formingis defined as any method that is performed at a temperaturebelow 1,300°F (705°C) and produces strain in the material.The calculations of cold strains shall be made in accordancewith PG-19.

PG-21 MAXIMUM ALLOWABLE WORKINGPRESSURE

The maximum allowable working pressure is the pres-sure determined by employing the allowable stress values,

11

design rules, and dimensions designated in this Section.Whenever the term maximum allowable working pres-

sure is used in this Section of the Code, it refers to gagepressure, or the pressure above atmosphere.

PG-21.1 No boiler, except a forced-flow steam genera-tor with no fixed steam and water line that meets the specialprovisions of PG-67, shall be operated at a pressure higherthan the maximum allowable working pressure exceptwhen the pressure relief valve or valves are discharging,at which time the maximum allowable working pressureshall not be exceeded by more than 6%.

PG-21.2 In a forced-flow steam generator with no fixedsteam and waterline it is permissible to design the pressureparts for different pressure levels along the path of water-steam flow. The maximum allowable working pressure ofany part shall be not less than that required by the rulesof Part PG for the expected maximum sustained conditions9

of pressure and temperature to which that part is subjectedexcept when one or more of the overpressure protectiondevices covered by PG-67.4 is in operation.

PG-22 LOADINGSPG-22.1 Stresses due to hydrostatic head shall be taken

into account in determining the minimum thicknessrequired unless noted otherwise. Additional stressesimposed by effects other than working pressure or statichead that increase the average stress by more than 10% ofthe allowable working stress shall also be taken intoaccount. These effects include the weight of the componentand its contents, and the method of support.

PG-22.2 Loading on structural attachments — refer toPW-43.

PG-23 STRESS VALUES FORCALCULATION FORMULAS

PG-23.1 The maximum allowable stress values inTables 1A and 1B of Section II, Part D, are the unit stressesto be used in the formulas of this Section to calculate theminimum required thickness or the maximum allowableworking pressure of the pressure part (see Appendix 1 ofSection II, Part D).

PG-23.2 The yield strength values for use in PFT-51may be found in Table Y-1 of Section II, Part D.

PG-23.3 With the publication of the 2004 Edition,Section II Part D is published as two separate publications.

9 “Expected maximum sustained conditions of pressure and tempera-ture” are intended to be selected sufficiently in excess of any expectedoperating conditions (not necessarily continuous) to permit satisfactoryboiler operation without operation of the overpressure protection devices.



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2010 SECTION I

TABLE PG-19POST COLD-FORMING STRAIN LIMITS AND HEAT-TREATMENT REQUIREMENTS

Minimum Heat-Treatment

Limitations in Higher Temperature WhenLimitations in Lower Temperature Range Temperature Range Design TemperatureFor Design Temperature For Design and Forming StrainAnd

But Less Than Temperature Limits are ExceededAnd Forming FormingExceeding or Equal to Exceeding [Notes (1) and (2)]UNS Strains Strains

Grade Number °F °C °F °C Exceeding °F °C Exceeding °F °C

304 S30400 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 1,900 (1 040)304H S30409 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 1,900 (1 040)304N S30451 1,075 (580) 1,250 (675) 15% 1,250 (675) 10% 1,900 (1 040)309S S30908 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 2,000 (1 095)310H S31009 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 2,000 (1 095)310S S31008 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 2,000 (1 095)310HCbN S31042 1,000 (540) 1,250 (675) 15% 1,250 (675) 10% 2,000 (1 095)316 S31600 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 1,900 (1 040)316H S31609 1,075 (580) 1,250 (675) 20% 1,250 (675) 10% 1,900 (1 040)316N S31651 1,075 (580) 1,250 (675) 15% 1,250 (675) 10% 1,900 (1 040)321 S32100 1,000 (540) 1,250 (675) 15% [Note (3)] 1,250 (675) 10% 1,900 (1 040)321H S32109 1,000 (540) 1,250 (675) 15% [Note (3)] 1,250 (675) 10% 2,000 (1 095)347 S34700 1,000 (540) 1,250 (675) 15% 1,250 (675) 10% 1,900 (1 040)347H S34709 1,000 (540) 1,250 (675) 15% 1,250 (675) 10% 2,000 (1 095)347HFG S34710 1,000 (540) 1,250 (675) 15% 1,250 (675) 10% 2,150 (1 175)348 S34800 1,000 (540) 1,250 (675) 15% 1,250 (675) 10% 1,900 (1 040)348H S34809 1,000 (540) 1,250 (675) 15% 1,250 (675) 10% 2,000 (1 175)230 N06230 1,100 (595) 1,400 (760) 15% 1,400 (760) 10% 2,200 (1 205)600 N06600 1,075 (580) 1,200 (650) 20% 1,200 (650) 10% 1,900 (1 040)601 N06601 1,075 (580) 1,200 (650) 20% 1,200 (650) 10% 1,900 (1 040)617 N06617 1,200 (650) 1,400 (760) 15% 1,400 (760) 10% 2,100 (1 150)690 N06690 1,075 (580) 1,200 (650) 20% 1,200 (650) 10% 1,900 (1 040)800 N08800 1,100 (595) 1,250 (675) 15% 1,250 (675) 10% 1,800 (980)800H N08810 1,100 (595) 1,250 (675) 15% 1,250 (675) 10% 2,050 (1 120). . . S30815 1,075 (580) 1,250 (675) 15% 1,250 (675) 10% 1,920 (1 050)

C-22 N06022 1,075 (580) 1,250 (675) 15% . . . . . . . . . 2,050 (1 120)

GENERAL NOTE: The limits shown are for cylinders formed from plates, spherical or dished heads formed from plate, and tube and pipe bends.When the forming strains cannot be calculated as shown in PG-19, the forming strain limits shall be half those tabulated in this Table (see PG-19.1).

NOTES:(1) Rate of cooling from heat-treatment temperature not subject to specific control limits.(2) While minimum heat-treatment temperatures are specified, it is recommended that the heat-treatment temperature range be limited to 150°F

(85°C) above that minimum [250°F (140°C) temperature range for 347, 347H, 348, and 348H].(3) For simple bends of tubes or pipes whose outside diameter is less than 3.5 in. (89 mm), this limit is 20%.

12



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2010 SECTION I

TABLE PG-20POST COLD-FORMING STRAIN LIMITS AND HEAT-TREATMENT REQUIREMENTS

Limitations in HigherLimitations in Lower Temperature Range Temperature RangeFor Design Temperature For Design Required Heat-Treatment When

But Less Than Temperature Design Temperature andExceeding or Equal to ExceedingUNS And Forming And Forming Forming Strain Limits are

Grade Number °F °C °F °C Strains °F °C Strains Exceeded

91 K90901 1,000 (540) 1,115 (600) > 25% 1,115 (600) > 20% Normalize and temper[Note (1)]

1,000 (540) 1,115 (600) > 5 to ≤ 25% 1,115 (600) > 5 to ≤ 20% Post-bend heat treatment[Notes (2)–(4)]

92 K92460 1,000 (540) 1,115 (600) > 25% 1,115 (600) > 20% Normalize and temper[Note (1)]

1,000 (540) 1,115 (600) > 5 to ≤ 25% 1,115 (600) > 5 to ≤ 20% Post-bend heat treatment[Notes (2)–(4)]

GENERAL NOTE: The limits shown are for cylinders formed from plates, spherical or dished heads formed from plate, and tube and pipe bends.The forming strain limits tabulated in the table shall be divided by two if PG-19.1 is applied. For any material formed at 1,300°F (705°C) orabove, and for cold swages, flares, or upsets, normalizing and tempering is required regardless of the amount of strain.

NOTES:(1) Normalization and tempering shall be performed in accordance with the requirements in the base material specification, and shall not be

performed locally. The material shall either be heat treated in its entirety, or the cold strained area (including the transition to the unstrainedportion) shall be cut away from the balance of the tube or component and heat treated separately or replaced.

(2) Post bend heat treatments shall be performed at 1350°F to 425°F (730°C to 775°C) for 1 hr/in. (1 hr/25 mm) or 30 min minimum.Alternatively, a normalization and temper in accordance with the requirements in the base material specification may be performed.

(3) For materials with greater than 5% strain but less than or equal to 25% strain with design temperatures less than or equal to 1,115°F(600°C), if a portion of the component is heated above the heat treatment temperature allowed above, one of the following actions shall beperformed:

(a) The component in its entirety must be renormalized and tempered.(b) The allowable stress shall be that for Grade 9 material (i.e., SA-213 T9, SA-335 P9, or equivalent product specification) at the design

temperature, provided that portion of the component that was heated to a temperature exceeding the maximum holding temperature is subjectedto a final heat treatment within the temperature range and for the time required in Note (2) above. The use of this provision shall be notedon the Manufacturer’s Data Report.

(4) If a longitudinal weld is made to a portion of the material that is cold strained, that portion shall be normalized and tempered, prior to orfollowing welding. This normalizing and tempering shall not be performed locally.

One publication contains values only in U.S. Customaryunits and the other contains values only in SI units. Theselection of the version to use is dependent on the set ofunits selected for analysis.

PG-25 QUALITY FACTORS FOR STEELCASTINGS

A quality factor as specified below shall be applied tothe allowable stresses for steel casting materials given inTable 1A of Section II, Part D.

PG-25.1 A factor not to exceed 80% shall be appliedwhen a casting is inspected only in accordance with theminimum requirements of the specification for the material,except when the special methods of examination prescribedby the selected specification are followed, thus permittingthe use of the applicable higher factor in this paragraph.

13

PG-25.2 A factor not to exceed 100% shall be appliedwhen the casting meets the requirements of PG-25.2.1through PG-25.2.4.

PG-25.2.1 All steel castings 41⁄2 in. (114 mm) nomi-nal body thickness or less, other than steel flanges andfittings complying with ASME B16.5, and valves comply-ing with ASME B16.34, shall be inspected as specified inPG-25.2.1.1 through PG-25.2.1.5.

PG-25.2.1.1 All critical areas, including the junc-tions of all gates, risers, and abrupt changes in section ordirection and weld-end preparations, shall be radiographedin accordance with Article 2 of Section V, and the radio-graphs shall conform to the requirements of ASTM E 446,Standard Reference Radiographs for Steel Castings Up to2 in. (51 mm) in Thickness, or ASTM E 186, StandardReference Radiographs for Heavy Walled [2 in. to 41⁄2 in.(51 mm to 114 mm)] Steel Castings, depending upon the

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2010 SECTION I

section thickness. The maximum acceptable severity levelfor 100% quality factor shall be

For ASTM E 446 [castings up to 2 in. (51 mm) thickness]

Severity Level

Up to and Greater ThanIncluding 1 in. (25 mm)

Imperfection Category 1 in. (25 mm) Thick Thick

A 1 2B 2 3C Types 1, 2, 3, and 4 1 3D, E, F, and G None None

acceptable acceptable

For ASTM E 186 [castings 2 in. to 41⁄2 in. (51 mm to114 mm) thickness]

Imperfection Category Severity Level

A and B, Types 1 and 2 of C 2Type 3 of C 3D, E, and F None acceptable

PG-25.2.1.2 All surfaces of each casting, includ-ing machined gasket seating surfaces, shall be examinedafter heat treatment by the magnetic particle method inaccordance with PG-25.2.1.2.1 or by the liquid penetrantmethod in accordance with PG-25.2.1.2.2.

PG-25.2.1.2.1 The technique for magnetic par-ticle examination shall be in accordance with Article 7 ofSection V. Imperfections causing magnetic particle indica-tions exceeding degree 1 of Type I, degree 2 of Type II,and degree 3 of Type III, and exceeding degree 1 of TypesIV and V of ASTM E 125, Standard Reference Photographsfor Magnetic Particle Indications on Ferrous Castings, areunacceptable.

PG-25.2.1.2.2 The technique for liquid pene-trant examination shall be in accordance with Article 6of Section V. Surface indications determined by liquidpenetrant examination are unacceptable if they exceed thefollowing:

(a) all cracks and hot tears

(b) any group of more than six linear indications otherthan those in (a) in any rectangular area of 11⁄2 in. � 6 in.(38 mm � 150 mm) or less, or any circular area havinga diameter of 31⁄2 in. (89 mm) or less, these areas being takenin the most unfavorable location relative to the indicationsbeing evaluated

(c) other linear indications more than 1⁄4 in. (6 mm) longfor thicknesses up to 3⁄4 in. (19 mm) inclusive, more thanone-third of the thickness in length for thicknesses from3⁄4 in. to 21⁄4 in. (19 mm to 57 mm), and more than 3⁄4 in.(19 mm) long for thicknesses over 21⁄4 in. (57 mm) (Aligned

14

acceptable indications separated from one another by adistance equal to the length of the longer indication areacceptable.)

(d) all indications of nonlinear imperfections that haveany dimension exceeding 3⁄16 in. (5 mm)

PG-25.2.1.3 Where more than one casting of aparticular design is produced, each of the first five castingsshall be inspected as above. Where more than five castingsare being produced, the examination shall be performedon the first five plus one additional casting to represent eachfive additional castings. If this additional casting proves tobe unacceptable, each of the remaining castings in thegroup shall be inspected.

PG-25.2.1.4 Any indications in excess of the max-imum permitted in PG-25.2.1.1 and PG-25.2.1.2 shall because for rejection unless the casting is repaired by weldingafter the base metal has been inspected to ensure that theimperfection has been removed or reduced to an acceptablesize. The completed repair shall be subject to reinspectionby the same method as was used in the original inspectionand the repaired casting shall be postweld heat treated.

PG-25.2.1.5 All welding shall be performed usingwelding procedures qualified in accordance with SectionIX. The procedure qualification shall be performed on testspecimens of cast material of the same specification andsubjected to the same heat treatment before and after weld-ing as will be applied to the work. All welders and operatorsperforming this welding shall also be qualified in accor-dance with Section IX.

PG-25.2.2 All steel castings having a body greaterthan 41⁄2 in. (114 mm) nominal thickness shall be inspectedas specified in PG-25.2.2.1 through PG-25.2.2.6.

PG-25.2.2.1 All surfaces of each casting, includ-ing machined gasket seating surfaces, shall be examinedafter heat treatment by the magnetic particle method inaccordance with PG-25.2.1.2.1 or liquid penetrant methodin accordance with PG-25.2.1.2.2.

PG-25.2.2.2 All parts of castings shall be sub-jected to complete radiographic inspection in accordancewith Article 2 of Section V, and the radiographs shallconform to the requirements of ASTM E 280, StandardReference Radiographs for Heavy Walled [41⁄2 in. to 12 in.(114 mm to 305 mm)] Steel Castings.

The maximum acceptable severity level for a 100% qual-ity factor shall be

Imperfection Category Severity Level

A, B, and Types 1, 2, and 3 of C 2D, E, and F None acceptable



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2010 SECTION I

PG-25.2.2.3 Any indications in excess of the max-imum permitted in PG-25.2.2.1 and PG-25.2.2.2 are unac-ceptable. The casting may be repaired by welding after thebase metal has been magnetic particle or dye penetrantinspected to ensure that the imperfection has been removedor reduced to an acceptable size.

PG-25.2.2.4 All weld repairs of depth exceeding1 in. (25 mm) or 20% of the section thickness, whicheveris less, shall be inspected by radiography in accordancewith PG-25.2.2.2 and by magnetic particle or dye penetrantinspection of the finished weld surface. All weld repairsof depth less than 20% of the section thickness, or 1 in.(25 mm), whichever is less, and all weld repairs of sectionswhich cannot be effectively radiographed shall be exam-ined by magnetic particle or dye penetrant inspection ofthe first layer, of each 1⁄4 in. (6 mm) thickness of depositedweld metal and of the finished weld surface. Magneticparticle or dye penetrant testing of the finished weld surfaceshall be done after postweld heat treatment.

PG-25.2.2.5 When repair welding is done afterheat treatment of the casting, the casting shall be postweldheat treated.

PG-25.2.2.6 All welding shall be performed usingwelding procedures qualified in accordance with SectionIX. The procedure qualification shall be performed on testspecimens of cast material of the same specification andsubjected to the same heat treatment before and after weld-ing as will be applied to the work. All welders and operatorsperforming this welding shall also be qualified in accor-dance with Section IX.

PG-25.2.3 Identification and Marking. Each cast-ing to which a quality factor greater than 80% is appliedshall be marked with the name, trademark, or other trace-able identification of the manufacturer and the casting iden-tification, including the casting quality factor and materialdesignation.

PG-25.2.4 Personnel performing radiographic, mag-netic particle, or liquid penetrant examinations under thisparagraph shall be qualified in accordance with theiremployer’s written practice. SNT-TC-1A10 or CP-189 shallbe used as a guideline for employers to establish theirwritten practice for qualification and certification of theirpersonnel.

When personnel have been certified according to theiremployer’s written practice based upon an edition ofSNT-TC-1A or CP-189 earlier than that referenced inA-360, their certification shall be valid for performingnondestructive examination required by this Section untiltheir next scheduled recertification. Any recertifications,

10 SNT-TC-1A and CP-189 are published by the American Society forNondestructive Testing, 1711 Arlingate Lane, P.O. Box 28518, Columbus,OH 43228-0518.

15

reexaminations, or new examinations shall be performedto the employer’s written practice based on the edition ofSNT-TC-1A or CP-189 referenced in A-360.

PG-26 WELD JOINT STRENGTHREDUCTION FACTOR

At elevated temperatures, the long-term strength of weldjoints can be lower than the long-term strength of thebase material. Table PG-26 specifies a weld joint strengthreduction factor, w, to be used to account for this lowerlong-term strength in determining the required thicknessof components operating in the creep range. This factorshall be applied in the design of cylinders containing longi-tudinal butt welds and to hemispherical heads or any otherspherical sections that comprise segments joined by weld-ing. As defined in PW-11.2, longitudinal butt welds shall beinterpreted to include spiral (helical) welds. Weld strengthreduction factors apply to such seams made by any weldingprocess, with or without filler metal added, regardlesswhether the welding is performed as part of material manu-facture or by the Certificate Holder as part of Section Ifabrication. The designer is responsible for determiningthe applicability of weld joint strength reduction factors toother (e.g., circumferential) welds. The weld joint strengthreduction factor is not required when evaluating occasionalloads, such as wind and earthquake.

PG-27 CYLINDRICAL COMPONENTSUNDER INTERNAL PRESSURE

PG-27.1 General. Unless the requirements of A-317 ofAppendix A are selected, the formulas under this paragraphshall be used to determine the minimum required thicknessor the maximum allowable working pressure of piping,tubes, drums, shells, and headers in accordance with theappropriate dimensional categories as given in PG-27.2.1,PG-27.2.2, and PG-27.2.3 for temperatures not exceedingthose given for the various materials listed in Tables 1Aand 1B of Section II, Part D.

The calculated and ordered thickness of material mustinclude the requirements of PG-16.2, PG-16.3, andPG-16.4. Stress calculations must include the loadings asdefined in PG-22 unless the formula is noted otherwise.

When required by the provisions of this Code, allowancemust be provided in material thickness for threading andminimum structural stability (see PWT-9.2 and PG-27.4,Notes 3 and 5).

If local thin areas are present in cylindrical shells, therequired thickness may be less than the thickness deter-mined in PG-27 provided the requirements of MandatoryAppendix IV are met.

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(10) TABLE PG-26WELD STRENGTH REDUCTION FACTORS TO BE APPLIED WHEN CALCULATING MAXIMUM ALLOWABLE

WORKING PRESSURE OR MINIMUM REQUIRED THICKNESS OF COMPONENTS FABRICATED WITH ALONGITUDINAL SEAM WELD

Temperature,°F 700 750 800 850 900 950 1,000 1,050 1,100 1,150 1,200 1,250 1,300 1,350 1,400 1,450 1,500Temperature, °C 371 399 427 454 482 510 538 566 593 621 649 677 704 732 760 788 816

Steel Group Weld Strength Reduction Factor [Notes (1)–(6)]

C-Mo [Note (7)] . . . . . . 1.00 NP NP NP NP NP NP NP NP NP NP NP NP NP NP

Cr-Mo [Notes (8), (9)] . . . . . . 1.00 0.95 0.91 0.86 0.82 0.77 0.73 0.68 0.64 NP NP NP NP NP NP

CSEF (N+T) [Notes (9)–(11)] . . . . . . . . . . . . . . . 1.00 0.95 0.91 0.86 0.82 0.77 NP NP NP NP NP NPCSEF (subcrit.) [Notes (9), . . . . . . . . . . . . 1.00 0.50 0.50 0.50 0.50 0.50 0.50 NP NP NP NP NP NP(12)]

Austenitic stainlesssteels and alloys800H (N08800) and800HT (N08810)[Notes (13), (14)] . . . . . . . . . . . . . . . 1.00 0.95 0.91 0.86 0.82 0.77 0.73 0.68 0.64 0.59 0.55 0.50

Autogenously weldedaustenitic stainless[Note (15)] . . . . . . . . . . . . . . . 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00

GENERAL NOTE: Nothing in this table shall be construed to permit materials that are not permitted by PG-5 through PG-9 of this Section orto permit use of materials at temperatures beyond limitations established by this Section. Several materials covered by this table are currentlypermitted for Section I application only via code case.

NOTES:(1) Cautionary Note: There are many factors that may affect the life of a welded joint at elevated temperature, and all of those factors cannot

be addressed in a table of weld strength reduction factors. For example, fabrication issues such as the deviation from a true circular formin pipe (e.g., “peaking” at longitudinal weld seams) or offset at the weld joint can cause an increase in stress that may result in reducedservice life, and control of these deviations is recommended.

(2) NP p not permitted.(3) Components made from carbon steel are exempt from the requirements of PG-26 and Table PG-26.(4) Longitudinal seam welds in components made from materials not covered in this table operating in the creep regime are not permitted. For

the purposes of this table, the creep regime temperature range is defined to begin at a temperature 50°F (25°C) below the T-note temperaturelisted in Section II, Part D design property tables for the base material involved.

(5) All weld filler metal shall have a minimum carbon content of 0.05% for the Cr-Mo and CSEF materials and a minimum carbon content of0.04% for the austenitic stainless steels.

(6) At temperatures below those where WSRFs are tabulated, a value of 1.0 shall be used for the factor w where required by the rules of thisSection; however, the additional rules of this table and notes do not apply.

(7) Longitudinal seam fusion welded construction is not permitted for C-1⁄2Mo steel above 850°F (454°C).(8) The Cr-Mo steels include 1⁄2Cr-1⁄2Mo, 1Cr-1⁄2Mo, 11⁄4Cr-1⁄2Mo-Si, 21⁄4Cr-1Mo, 3Cr-1Mo, and 5Cr-1⁄2Mo. Longitudinal welds shall either be

normalized, normalized and tempered, or subjected to proper subcritical PWHT for the alloy.(9) Basicity index of SAW flux ≥ 1.0.(10) N + T p normalizing + tempering PWHT.

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TABLE PG-26WELD STRENGTH REDUCTION FACTORS TO BE APPLIED WHEN CALCULATING MAXIMUM ALLOWABLE

WORKING PRESSURE OR MINIMUM REQUIRED THICKNESS OF COMPONENTS FABRICATED WITH ALONGITUDINAL SEAM WELD (CONT’D)

(11) The CSEF (creep strength enhanced ferritic) steels include Grades 91, 92, 911, 122, and 23.(12) subcrit. p subcritical PWHT is required. No exemptions from PWHT are permitted. The PWHT time and temperature shall meet the

requirements of Table PW-39; the alternative PWHT requirements of Table PW-39.1 are not permitted.(13) Certain heats of the austenitic stainless steels, particularly for those grades whose creep strength is enhanced by the precipitation of temper-

resistant carbides and carbo-nitrides, can suffer from an embrittlement condition in the weld heat-affected zone that can lead to prematurefailure of welded components operating at elevated temperatures. A solution annealing heat treatment of the weld area mitigates thissusceptibility.

(14) Alternatively, the following factors may be used as the weld joint strength reduction factor for the materials and welding consumablesspecified, provided the weldment is solution annealed after welding.

Temperature, °F 950 1,000 1,050 1,100 1,150 1,200 1,250 1,300 1,350 1,400 1,450 1,500Temperature, °C 510 538 566 593 621 649 677 704 732 760 788 816

Materials Weld Strength Reduction Factor

Type 304 stainless steel welded withSFA-5.22 EXXXT-G (16-8-2 chemistry),SFA 5.4E 16-8-2, and SFA-5.9 ER 16-8-2 1.00 1.00 1.00 1.00 1.00 1.00

Type 316 stainless steel welded withSFA-5.22 EXXXT-G (16-8-2 chemistry),SFA 5.4 E 16-8-2, and SFA-5.9 ER 16-8-2 1.00 0.85 0.90 0.97 0.99 1.00

(15) Autogenous welds (without weld filler metal) in austenitic SS materials have been assigned a WSRF of 1.00 up 1,500°F (816°C), providedthat the product is solution annealed after welding and receives nondestructive electric examination, in accordance with the materialspecification.

PG-27.2 Formulas for CalculationPG-27.2.1 Tubing — Up to and Including 5 in.

(125 mm) Outside DiameterFor bare tubes or bimetallic tubes when the strength of

the clad is not included,11 use the following equations:

t pPD

2Sw + P+ 0.005D + e

P p Sw� 2t − 0.01D − 2eD − (t − 0.005D − e)�

See PG-27.4.2, PG-27.4.4, PG-27.4.8, and PG-27.4.10.For bimetallic tubes when the strength of the clad is

included,11 use the following equations:

tb + tc′ pPD

2Sb + P+ 0.005D + e

tc′ p tc�ScSb�

t p tb + tc

P p Sb� 2(tb + tc′) − 0.01D − 2eD − [(tb + tc′) − 0.005D − e]�

11 Generalized wastage and localized corrosion, including stress corro-sion cracking, have been observed in the clad of bimetallic tubes in someapplications, such as chemincal recovery boilers. In such applications,the choice of whether or not to include the clad strength may criticallyaffect service performance, dependent on the environmental susceptibilityof the clad.

17

See PG-27.4.4, PG-27.4.8, PG-27.4.10, and PG-27.4.11.

PG-27.2.1.2 The wall thickness of the ends oftubes strength-welded to headers or drums need not bemade greater than the run of the tube as determined bythese formulas.

PG-27.2.1.3 The wall thickness of the ends oftubes permitted to be attached by threading under the limi-tations of PWT-9.2 shall be not less than t as determinedby this formula, plus 0.8 /n (20/n), where n equals thenumber of threads per inch (per mm).

PG-27.2.1.4 A tube in which a fusible plug is tobe installed shall be not less than 0.22 in. (5.6 mm) inthickness at the plug in order to secure four full threadsfor the plug (see also A-20).

PG-27.2.1.5 Bimetallic tubes for which thestrength of the clad is not included and meeting the require-ments of PG-9.4 shall use an outside diameter, D, in theappropriate equation in PG-27.2.1 no less than the calcu-lated outside diameter of the core material. The outsidediameter of the core material shall be determined by sub-tracting twice the minimum thickness of the cladding fromthe outside diameter of the bimetallic tube, including themaximum plus tolerance of the core tube. The minimumrequired thickness, t, shall apply only to the core material.

Tubes for which the strength of the clad is included andmeeting the requirements of PG-9.4 shall use an outsidediameter, D, in the appropriate equation in PG-27.2.1 equal



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to the outside diameter of the bimetallic tube, includingthe maximum plus tolerance for both the core tube diameterand clad thickness.

PG-27.2.2 Piping, Drums, Shells, and Headers.(based on strength of weakest course)

t pPD

2SE + 2yP+ C or

PRSE − (1 − y)P

+ C

P p2SE(t − C)

D − 2y (t − C)or

SE(t − C)R + (1 − y)( t− C)

See PG-27.4.1, PG-27.4.3, and PG-27.4.5 throughPG-27.4.9.

PG-27.2.3 Thickness Greater Than One-Half theInside Radius of the Component. The maximum allow-able working pressure for parts of boilers of cylindricalcross section, designed for temperatures up to that of satu-rated steam at critical pressure [705.4°F (374.1°C)], shallbe determined by the formulas in A-125.

PG-27.3 Symbols. Symbols used in the preceding for-mulas are defined as follows:

C p minimum allowance for threading and structuralstability (see PG-27.4.3)

D p outside diameter of cylinderE p efficiency (see PG-27.4.1)e p thickness factor for expanded tube ends (see

PG-27.4.4)P p maximum allowable working pressure (see

PG-21)R p inside radius of cylinderS p maximum allowable stress value at the design

temperature of the metal, as listed in the tablesspecified in PG-23 (see PG-27.4.2)

Sb p maximum allowable stress value at the designtemperature of the base metal, as listed in thetables specified in PG-23, for a bimetallic tube inwhich the clad strength is to be included (seePG-27.4.11)

Sc p maximum allowable stress value at the designtemperature of the clad metal, as listed in SectionII, Part D, Tables 1A or 1B, for a bimetallic tubein which the clad strength is to be included (seePG-27.4.11)

t p minimum required thickness (see PG-27.4.7)tb p minimum required thickness of the base metal for

a bimetallic tube in which the clad strength is tobe included (see PG-27.4.11)

tc p minimum required thickness of the clad for abimetallic tube in which the clad strength is to beincluded (see PG-27.4.11)

tc′ p minimum effective clad thickness for strengthpurposes for a bimetallic tube in which the cladstrength is to be included (see PG-27.4.11)

w p weld joint strength reduction factor per PG-26

18

y p temperature coefficient (see PG-27.4.6)

PG-27.4 Notes. Notes referenced in the preceding for-mulas are as follows:

PG-27.4.1 Note 1

E p 1.0 for seamless cylinders without openingsspaced to form ligaments

p the ligament efficiency per PG-52 or PG-53 forseamless cylinders with ligaments

p w, the weld joint strength reduction factor per PG-26, for longitudinally welded cylinders withoutligaments

For longitudinally welded cylinders with ligamentslocated such that no part of the longitudinal weld seam ispenetrated by the openings forming the ligament, E shallbe taken as the lesser of w or the ligament efficiency fromPG-52 or PG-53. If any part of the longitudinal seam weldis penetrated by the openings that form the ligaments, Eshall be taken as the product of w times the ligamentefficiency.

PG-27.4.2 Note 2. The temperature of the metal to beused in selecting the S value for tubes shall not be lessthan the maximum expected mean wall temperature, i.e.,the sum of the outside and inside tube surface temperaturesdivided by 2. For tubes that do not absorb heat, the metaltemperature may be taken as the temperature of the fluidwithin the tube but not less than the saturation temperature.

PG-27.4.3 Note 3. Any additive thickness representedby the general term C may be considered to be applied onthe outside, the inside, or both. It is the responsibility ofthe designer using these formulas to make the appropriateselection of diameter or radius to correspond to the intendedlocation and magnitude of this added thickness. The pres-sure- or stress-related terms in the formula should be evalu-ated using the diameter (or radius) and the remainingthickness which would exist if the “additive” thickness hadnot been applied or is imagined to have been entirelyremoved.

The values of C below do not include any allowancefor corrosion and/or erosion, and additional thicknessshould be provided where they are expected. Likewise, thisallowance for threading and minimum structural stability isnot intended to provide for conditions of misapplied exter-nal loads or for mechanical abuse.

Threaded Pipea Value of Cb in. (mm)

D ≤ 3⁄4 in. (19 mm) nominal 0.065 (1.65)D > 3⁄4 in. (19 mm) nominal Depth of thread hc

(a) Steel or nonferrous pipe lighter than Schedule 40of ASME B36.10M, Welded and Seamless Wrought SteelPipe, shall not be threaded.

(b) The values of C stipulated above are such that theactual stress due to internal pressure in the wall of the pipe

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is no greater than the values of S given in Table 1A ofSection II, Part D, as applicable in the formulas.

(c) The depth of thread h in in. (mm) may be determinedfrom the formula h p 0.8 /n (h p 20/n), where n is thenumber of threads per inch (25 mm) or from the following:

n h

8 0.100 (2.5)111⁄2 0.0696 (1.77)

PG-27.4.4 Note 4e p 0.04 (1.0) over a length at least equal to the length

of the seat plus 1 in. (25 mm) for tubes expandedinto tube seats, except

p 0 for tubes expanded into tube seats provided thethickness of the tube ends over a length of the seatplus 1 in. (25 mm) is not less than the following:

(a) 0.095 in. (2.41 mm) for tubes 11⁄4 in.(32 mm) O.D. and smaller

(b) 0.105 in. (2.67 mm) for tubes above 11⁄4 in.(32 mm) O.D. and up to 2 in. (50 mm) O.D., incl.

(c) 0.120 in. (3.05 mm) for tubes above 2 in.(50 mm) O.D. and up to 3 in. (75 mm) O.D., incl.

(d) 0.135 in. (3.43 mm) for tubes above 3 in.(76 mm) O.D. and up to 4 in. (100 mm) O.D.,incl.

(e) 0.150 in. (3.81 mm) for tubes above 4 in.(100 mm) O.D. and up to 5 in. (125 mm) O.D.,incl.

p 0 for tubes strength-welded to headers and drums

PG-27.4.5 Note 5. While the thickness given by theformula is theoretically ample to take care of both burstingpressure and material removed in threading, when steelpipe is threaded and used for steam pressures of 250 psi(1.7 MPa) and over, it shall be seamless and of a weightat least equal to Schedule 80 in order to furnish addedmechanical strength.

PG-27.4.6 Note 6y p a coefficient having values as follows:

Temperature, °F (°C)

900 1,250(480) 950 1,000 1,050 1,100 1,150 1,200 (675)and (510) (540) (565) (595) (620) (650) and

below above

Ferritic 0.4 0.5 0.7 0.7 0.7 0.7 0.7 0.7Austenitic 0.4 0.4 0.4 0.4 0.5 0.7 0.7 0.7Alloy 800, 801 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.7800H, 800HT 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.7825 0.4 0.4 0.4 . . . . . . . . . . . . . . .230 Alloy 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.7N06022 0.4 0.4 0.4 0.4 0.5 0.7 0.7 0.7N06045 0.4 0.4 0.4 0.4 0.5 0.7 0.7 0.7N06600 0.4 0.4 0.4 0.4 0.5 0.7 0.7 . . .N06601 0.4 0.4 0.4 0.4 0.5 0.7 0.7 . . .N06625 0.4 0.4 0.4 0.4 0.4 . . . . . . . . .N06690 0.4 0.4 0.4 0.4 0.5 0.7 0.7 . . .Alloy 617 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.7S31803 0.4 . . . . . . . . . . . . . . . . . . . . .

19

Values of y between temperatures listed may be deter-mined by interpolation. For nonferrous materials not listed,y p 0.4.

PG-27.4.7 Note 7. If pipe is ordered by its nominalwall thickness, as is customary in trade practice, the manu-facturing tolerance on wall thickness must be taken intoaccount. After the minimum pipe wall thickness t is deter-mined by the formula, this minimum thickness shall beincreased by an amount sufficient to provide the manufac-turing tolerance allowed in the applicable pipe specifica-tion. The next heavier commercial wall thickness may thenbe selected from Standard thickness schedules as containedin ASME B36.10M. The manufacturing tolerances aregiven in the several pipe specifications listed in PG-9.

PG-27.4.8 Note 8. When computing the allowable pres-sure for a pipe of a definite minimum wall thickness, thevalue obtained by the formulas may be rounded up to thenext higher unit of 10 psi (0.1 MPa).

PG-27.4.9 Note 9. Inside backing strips, when used atlongitudinal welded joints, shall be removed and the weldsurface prepared for volumetric examination as required.Inside backing rings may remain at circumferential weldedseams of cylinders provided such construction complieswith requirements of PW-41.

PG-27.4.10 Note 10. The maximum allowable workingpressure P need not include the hydrostatic head loading,PG-22, when used in this equation.

PG-27.4.11 Note 11. This note has additional require-ments for bimetallic tubes for which the strength of theclad is included. For additional fabrication requirements,see PW-44. For such bimetallic tubes, the thermal conduc-tivity of the base metal shall be equal to or greater thanthe thermal conductivity of the clad material. The claddingprocess shall achieve a metallurgical bond between theclad and the base metal (core tube).

The temperature of the metal to be used in selecting theSb value for core tubes shall not be less than the maximumexpected mean wall temperature calculated using the basemetal thermal properties for a tube with the same outsidediameter and total wall thickness as the clad tube, i.e., thesum of the outside and inside tube surface temperature ofan equivalent core tube, divided by 2.

The temperature of the metal to be used in selecting theSc value for the clad shall not be less than the maximumexpected mean wall temperature of the clad, i.e., the sumof the outside surface temperature and the base metal-cladinterface temperature, divided by 2.

The value of Sc shall be taken as that for an annealedwrought material with nominally equivalent strength andcomposition as the clad. Values applicable to eitherSection I or Section VIII, Division 1 may be used. If two

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FIG. PG-28 MAXIMUM INTERNAL PROJECTION OF WELDED ACCESS ORINSPECTION OPENINGS

Length past the toe

GENERAL NOTE: For other acceptable weld configurations, see Fig. PW-16.1.

stress values are listed for a material, the higher value maybe used.

The sizing equation is subject to the following con-straints:

tb ≥ tc (excludes clads thicker than core tube)

t <D4

(excludes thick-walled tubes)

If �ScSb� ≥ 1, the ratio is set to 1 in the calculation

If �ScSb� < 1, the actual ratio is used in the calculation

PG-28 WELDED ACCESS OR INSPECTIONOPENINGS UNDER EXTERNALPRESSURE

The maximum allowable working pressure for weldedaccess or inspection openings, with inward projections sub-jected to external pressure (such as manhole or handholerings with internal covers), may be determined in accor-dance with the rules of PG-27 when the following require-ments are met. The length of the internal projection of thering extending past the toe of the attachment weld on thering, shall not exceed the thickness of the ring. The lengthpast the toe of the weld is measured at the location of theshortest ring projection into the vessel (see Fig. PG-28). Forelliptical rings the value of D to be used in the procedures of

20

PG-27 shall be determined in accordance with the follow-ing equation for elliptical rings:

D p a2 / b

where

a p outside major axis of the ellipseb p outside minor axis of the ellipse

This provision does not apply to flanged in manholes cov-ered by PG-29.3, PG-29.7, and PG-29.12.

PG-29 DISHED HEADSPG-29.1 The thickness of a blank unstayed dished head

with the pressure on the concave side, when it is a segmentof a sphere, shall be calculated by the following equation:

t p 5PL / 4.8Sw

where

L p radius to which the head is dished, measured onthe concave side of the head

P p maximum allowable working pressure (hydro-static head loading need not be included)

S p maximum allowable working stress, using valuesgiven in Table 1A of Section II, Part D

t p minimum thickness of headw p weld joint strength reduction factor per PG-26

PG-29.1.1 If local thin areas are present in the spheri-cal portion of the dished head, the required thickness may

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be less than the thickness determined in PG-29.1 providedthe requirements of Mandatory Appendix IV are met.

PG-29.2 The radius to which a head is dished shall benot greater than the outside diameter of flanged portion ofthe head. Where two radii are used the longer shall betaken as the value of L in the equation.

PG-29.3 When a head dished to a segment of a spherehas a flanged-in manhole or access opening that exceeds6 in. (150 mm) in any dimension, the thickness shall beincreased by not less than 15% of the required thicknessfor a blank head computed by the above formula, but inno case less than 1⁄8 in. (3 mm) additional thickness overa blank head. Where such a dished head has a flangedopening supported by an attached flue, an increase in thick-ness over that for a blank head is not required. If morethan one manhole is inserted in a head, the thickness ofwhich is calculated by this rule, the minimum distancebetween the openings shall be not less than one-fourth ofthe outside diameter of the head.

PG-29.4 Except as otherwise provided for in PG-29.3,PG-29.7, and PG-29.12, all openings which require rein-forcement, placed in a head dished to a segment of a sphere,or in an ellipsoidal head, or in a full-hemispherical head,including all types of manholes except those of the integralflanged-in type, shall be reinforced in accordance with therules in PG-33.

When so reinforced, the thickness of such a head maybe the same as for a blank unstayed head.

PG-29.5 Where the radius L to which the head is dishedis less than 80% of the outside diameter of the head, thethickness of a head with a flanged-in manhole openingshall be at least that found by making L equal to 80% ofthe outside diameter of the head and with the added thick-ness for the manhole. This thickness shall be the minimumthickness of a head with a flanged-in manhole opening forany form of head and the maximum allowable workingstress shall not exceed the values given in Table 1A ofSection II, Part D.

PG-29.6 No head, except a full-hemispherical head,shall be of a lesser thickness than that required for a seam-less shell of the same diameter.

PG-29.7 A blank head of a semiellipsoidal form inwhich half the minor axis or the depth of the head is atleast equal to one-quarter of the inside diameter of thehead shall be made at least as thick as the required thicknessof a seamless shell of the same diameter as provided inPG-27.2.2. If a flanged-in manhole that meets the Coderequirements is placed in an ellipsoidal head, the thicknessof the head shall be the same as for a head dished to asegment of a sphere (see PG-29.1 and PG-29.5) with adish radius equal to eight-tenths the outside diameter of

21

the head and with the added thickness for the manhole asspecified in PG-29.3.

PG-29.8 When heads are made to an approximate ellip-soidal shape, the inner surface of such heads must lieoutside and not inside of a true ellipse drawn with themajor axis equal to the inside diameter of the head andone-half the minor axis equal to the depth of the head. Themaximum variation from this true ellipse shall not exceed0.0125 times the inside diameter of the head.

PG-29.9 Unstayed dished heads with the pressure onthe convex side shall have a maximum allowable workingpressure equal to 60% of that for heads of the same dimen-sions with the pressure on the concave side.

Head thicknesses obtained by using the formulas inPG-29.11 for hemispherical heads and PG-29.7 for blanksemiellipsoidal heads do not apply to heads with pressureon the convex side.

PG-29.11 The thickness of a blank unstayed full-hemi-spherical head with the pressure on the concave side shallbe calculated by the following equation:

t pPL

2Sw− 0.2P

where

L p radius to which the head was formed, measuredon the concave side of the head

P p maximum allowable working pressureS p maximum allowable working stress, using values

given in Table 1A of Section II, Part Dt p minimum thickness of head

w p weld joint strength reduction factor per PG-26

The above equation shall not be used when the requiredthickness of the head given by this formula exceeds 35.6%of the inside radius, and instead, the following equationshall be used:

t p L(Y1⁄

3 − 1)

where

Y p2(Sw+ P )

2Sw− P

Joints in full-hemispherical heads including the joint tothe shell shall be governed by and meet all the requirementsfor longitudinal joints in cylindrical shells, except that ina buttwelded joint attaching a head to a shell the middlelines of the plate thicknesses need not be in alignment.

If local thin areas are present in the full-hemisphericalhead, the required thickness may be less than the thicknessdetermined above provided the requirements of MandatoryAppendix IV are met.

PG-29.12 If a flanged-in manhole that meets the Coderequirements is placed in a full-hemispherical head, the

(10)

(10)



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(10)

2010 SECTION I

thickness of the head shall be the same as for a head dishedto a segment of a sphere (see PG-29.1 and PG-29.5), witha dish radius equal to eight-tenths the outside diameter ofthe head and with the added thickness for the manhole asspecified in PG-29.3.

PG-29.13 The corner radius of an unstayed dished headmeasured on the concave side of the head shall be not lessthan three times the thickness of the material in the head;but in no case less than 6% of the outside diameter of thehead. In no case shall the thinning-down due to the processof forming, of the knuckle portion of any dished headconsisting of a segment of a sphere encircled by a partof a torus constituting the knuckle portion (torispherical),exceed 10% of the thickness required by the formula inPG-29.1. Other types of heads shall have a thickness afterforming of not less than that required by the applicableequation.

PG-30 STAYED DISHED HEADSPG-30.1 When dished heads are of a thickness less than

called for by PG-29, they shall be stayed as flat surfaces, noallowance being made in such staying for the holdingpower due to the spherical form unless all of the followingconditions are met:

PG-30.1.1 That they be at least two-thirds as thickas called for by the rules for unstayed dished heads.

PG-30.1.2 That they be at least 7⁄8 in. (22 mm) inthickness.

PG-30.1.3 That through-stays be used attached tothe dished head by outside and inside nuts.

PG-30.1.4 That the maximum allowable workingpressure shall not exceed that calculated by the rules foran unstayed dished head plus the pressure correspondingto the strength of the stays or braces secured by the formulafor braced or stayed surfaces given in PG-46, using 1.3for the value of C.

PG-30.2 If a dished head concave to pressure is formedwith a flattened spot or surface, the diameter of the flatspot shall not exceed that allowable for flat heads as givenby the formula in PG-31, using C p 0.25.

PG-31 UNSTAYED FLAT HEADS ANDCOVERS

PG-31.1 The minimum thickness of unstayed flatheads, cover plates, and blind flanges shall conform to therequirements given in this paragraph. These requirementsapply to both circular and noncircular12 heads and covers.

12 Special consideration shall be given to the design of shells, nozzlenecks, or flanges to which noncircular heads or covers are attached (seePreamble, second paragraph).

22

Some acceptable types of flat heads and covers are shownin Fig. PG-31. In this figure, the dimensions of the welds areexclusive of extra metal required for corrosion allowance.

PG-31.2 The notations used in this paragraph and inFig. PG-31 are defined as follows:

C p a factor depending on the method of attachmentof head and on the shell, pipe, or header dimen-sions, and other items as listed in PG-31.4 below,dimensionless. The factors for welded covers alsoinclude a factor of 0.667 that effectively increasesthe allowable stress for such constructions to 1.5S.

D p long span of noncircular heads or covers measuredperpendicular to short span

d p diameter, or short span, measured as indicated inFig. PG-31

hg p gasket moment arm, equal to the radial distancefrom the center line of the bolts to the line of thegasket reaction, as shown in Fig. PG-31, illustra-tions (j) and (k)

L p perimeter of noncircular bolted head measuredalong the centers of the bolt holes

l p length of flange of flanged heads, measured fromthe tangent line of knuckle, as indicated in Fig.PG-31, illustrations (a) and (c)

m p the ratio tr /ts, dimensionlessP p maximum allowable working pressurer p inside corner radius on a head formed by flanging

or forgingS p maximum allowable stress value, psi (kPa), using

values given in Table 1A of Section II, Part Dt p minimum required thickness of flat head or covertf p nominal thickness of the flange on a forged head,

at the large end, as indicated in Fig. PG-31, illus-tration (b)

th p nominal thickness of flat head or covertr p thickness required for pressure of seamless shell,

pipe, or headerts p minimum specified thickness of shell, pipe, or

headertw p thickness through the weld joining the edge of a

head to the inside of a drum, pipe, or header, asindicated in Fig. PG-31, illustration (g)

t1 p throat dimension of the closure weld, as indicatedin Fig. PG-31, illustration (r)

W p total bolt load, as further defined in PG-31.3.2Z p a factor for noncircular heads and covers that

depends on the ratio of short span to long span,as given in PG-31.3, dimensionless

PG-31.3 The thickness of flat unstayed heads, covers,and blind flanges shall conform to one of the followingthree requirements.13

13 The formulas provide safe construction as far as stress is concerned.Greater thicknesses may be necessary if deflection would cause leakageat threaded or gasketed joints.



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2010 SECTION I

FIG. PG-31 SOME ACCEPTABLE TYPES OF UNSTAYED FLAT HEADS AND COVERS

(a)

(d)

Tangent line

Center of weld

Taper

ts

t

t

t

t

t

tts

0.7 ts

ts

ts

ts

ts

tf

r = 3t min.

tf min. = 2ts

r = 3tf min.r = 3t min.

d

d

(b)

C = 0.17

C = 0.13

0.7 tsMin. 0 in. (0 mm)

Min. 1/8 in. (3 mm)

1.25 tr min.

Not less than the smaller of ts or 1/4 in. (6 mm)

Min. included angle 30 deg with a min. of 15 deg on the head

Min. included angle 30 deg with a min. of 15 deg on the headMin. gap 1/8 in. (3 mm)

(m)

C = 0.30

(e)

See Note (1)

(c)

C = 0.30

d

Center of Lap

d

d

r = 1/4 t min.0.7 ts

0.7 ts

(f)

See Note (1)

(g-1)

See Note (1)

Continuation of shell optional

ts

0.8 ts min.

3/4 t min.

Projection beyond weld is optional

tw = 2 tr min. not less than 1.25 ts but need not be greater than t

dts

tst1

Min. t1 = t or ts whichever is greater

dBevel optional

45 deg max.

C = 0.33C = 0.33 m C min. = 0.20

(i-1) (i-2)

Retaining ringd

(n)

C = 0.30

30 deg min. 45 deg max.

(o)

C = 0.30

(s)

C = 0.33

(r)

C = 0.33

(q)

C = 0.75See Note (2)

(p)

C = 0.25

Threaded ring

tt

d d

dd

d

d

t

or

Seal weld

t

t

t

hG

d

(k)

C = 0.30 (Use Eq. 2 or 5)

t t

(j)

C = 0.3 (Use Eq. 2 or 5)

hG

dt t

t t t

t

t d t d

(g-2)

C = 0.33

Projection beyond weld is optional

tw = 2 tr min. not less than 1.25 ts but need not be greater than t

tsd

Bevel optional

45 deg max.t

GENERAL NOTE: The above illustrations are diagrammatic only. Other designs that meet the requirements of PG-31 will be acceptable.

NOTES:(1) For illustrations (e), (f), and (g-1) circular covers, C p 0.33m, C min. p 0.20; noncircular covers, C p 0.33.(2) When pipe threads are used, see Table PG-39.

23



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2010 SECTION I

PG-31.3.1 Circular blind flanges of ferrous materialsconforming to ASME B16.5 shall be acceptable for thediameters and pressure–temperature ratings in Table 2 ofthat Standard when of the types shown in Fig. PG-31,illustrations (j) and (k).

PG-31.3.2 The minimum required thickness of flatunstayed circular heads, covers, and blind flanges shall becalculated by the following equation:

t p d� CP/S (1)

except when the head, cover, or blind flange is attachedby bolts causing an edge moment [Fig. PG-31, illustrations(j) and (k)] in which case the thickness shall be calculatedby the following equation:

t p d� (CP/S) + (1.9Whg /Sd3) (2)

When using eq. (2) the thickness t shall be calculatedfor both design conditions and gasket seating, and thegreater of the two values shall be used. For design condi-tions, the value of P shall be the maximum allowableworking pressure, the value of S at design temperatureshall be used, and W shall be the sum of the bolt loadsrequired to resist the end pressure load and to maintaintightness of the gasket.14 For gasket seating, P equals zero,the value of S at atmospheric temperature shall be used,and W shall be the average of the required bolt load andthe load available from the bolt area actually used.

PG-31.3.3 Flat unstayed heads, covers, or blindflanges may be square, rectangular, elliptical, obround,segmental, or otherwise noncircular. Their required thick-ness shall be calculated by the following equation:

t p d� ZCP/S (3)

where

Z p 3.4 −2.4d

D(4)

with the limitation that Z need not be greater than 21⁄2.Equation (3) does not apply to noncircular heads, covers,

or blind flanges attached by bolts causing a bolt edgemoment [Fig. PG-31, illustrations (j) and (k)]. For noncir-

14 Equations for W may be found in any of several references, suchas the following:

“Modern Flange Design,” Bulletin 502, 7th Edition; G+W Taylor-Bonney Division, Southfield, Michigan.

Jawad, M. H. and Farr, J. R., Structural Analysis and Design of ProcessEquipment, Second Edition; John Wiley & Sons.

ASME BPVC, Section VIII, Division 1, “Rules for Construction ofPressure Vessels,” Appendix 2, “Rules for Bolted Flange Connectionwith Risk Type Gaskets”; The American Society of Mechanical Engineers(ASME International), Three Park Avenue, New York, NY 10016; OrderDept.: 22 Law Drive, Box 2300, Fairfield, NJ 07007-2300.

24

cular heads of this type, the required thickness shall becalculated by the following equation:

t p d� (ZCP/S) + (6Whg /SLd2) (5)

When using eq. (5), the thickness t shall be calculatedin the same way as specified above for eq. (2).

PG-31.4 For the types of construction shown in Fig.PG-31, the minimum values of C to be used in eqs. (1)through (3) and (5) are:15

Fig. PG-31, illustration (a): C p 0.17 for flanged circularand noncircular heads forged integral with or buttweldedto the shell, pipe, or header, with an inside corner radiusnot less than three times the required head thickness, withno special requirement with regard to length of flange, andwhere the welding meets all the requirements for circumfer-ential joints given in Part PW.

C p 0.10 for circular heads, where the flange lengthfor heads of the above design is not less than

l p �1.1 − 0.8ts

2

th2� � dth (6)

When C p 0.10 is used, the slope of the tapered sectionsshall be no greater than 1:3.

Fig. PG-31, illustration (b): C p 0.17 for circular andnoncircular heads forged integral with or buttwelded to theshell, pipe, or header, where the corner radius on the insideis not less than three times the thickness of the flange andwhere the welding meets all the requirements for circumfer-ential joints given in Part PW.

Fig. PG-31, illustration (c): C p 0.30 for circular flangedplates screwed over the end of the shell, pipe, or header,with inside corner radius not less than 3t, in which thedesign of the threaded joint against failure by shear, tension,or compression, resulting from the end force due to pres-sure, is based on a factor of safety of at least 4, and thethreaded parts are at least as strong as the threads forstandard piping of the same diameter. Seal welding maybe used, if desired.

Fig. PG-31, illustration (d): C p 0.13 for integral flatcircular heads when the dimension d does not exceed 24 in.(600 mm); the ratio of thickness of the head to the dimen-sion d is not less than 0.05 nor greater than 0.25; the headthickness th is not less than the shell thickness ts , the insidecorner radius is not less than 0.25t; and the constructionis obtained by special techniques of upsetting and spinningthe end of the shell, pipe, or header, such as are employedin closing header ends.

Fig. PG-31, illustrations (e), (f), and (g-1): C p 0.33mbut not less than 0.20 for circular plates and C p 0.33 fornoncircular plates welded to the inside of a drum, pipe, or

15 Volumetric examination is not required for any of the weld jointsshown in Fig. PG-31, illustrations (e), (f), (g-1), (g-2), (i), (r), and (s).

(10)



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2010 SECTION I

header, and otherwise meeting the requirements for therespective types of welded boiler drums, including post-weld heat treatment when required for the drum, but omit-ting volumetric examination. If a value of m less than 1is used in calculating t, the shell thickness, ts, shall bemaintained along a distance inwardly from the inside faceof the head equal to at least 2� dts. The throat thicknessof the fillet welds in illustrations (e) and (f) shall be atleast 0.7ts. The size of the weld tw in illustration (g-1) shallbe not less than 2 times the required thickness of a seamlessshell nor less than 1.25 times the nominal shell thicknessbut need not be greater than the head thickness; the weldshall be deposited in a welding groove with the root of theweld at the inner face of the head as shown in the figure.

Fig. PG-31, illustration (g-2): C p 0.33 for circularplates, welded to the inside of a drum, pipe, or header, andotherwise meeting the requirements for the respective typesof welded boiler drums, including postweld heat treatmentwhen required for the drum, but omitting volumetric exami-nation. When the weld is not deposited at the inner face ofthe header, the thickness of the head that remains unweldedshall be in addition to the thickness of the head calculatedper PG-31.3.2. The drum or header shall be limited to NPS4 or less.

C p 0.33 for noncircular plates, welded to the insideof a drum, pipe, or header, and otherwise meeting therequirements for the respective types of welded boilerdrums, including postweld heat treatment when requiredfor the drum, but omitting volumetric examination. Thethroat thickness of the fillet welds in Fig. 31, illustrations(e) and (f) shall be at least 0.7ts. The size of the weld tw inillustration (g-1) shall be not less than 2 times the requiredthickness of a seamless shell nor less than 1.25 times thenominal shell thickness but need not be greater than thehead thickness; the weld shall be deposited in a weldinggroove with the root of the weld at the inner face of thehead as shown in the figure.

Fig. PG-31, illustration (i): C p 0.33m but not less than0.20 for circular plates welded to the end of the drum,pipe, or header, when an inside weld with minimum throatthickness of 0.7ts is used. The width at the bottom of thewelding groove shall be not less than 1⁄8 in. (3 mm) andthe exposed edge not less than ts or 1⁄4 in. (6 mm), whicheveris smaller. The inside fillet weld may be omitted, providingts is not less than 1.25tr and the factor C is taken as 0.33.

Fig. PG-31, illustrations (j) and (k): C p 0.3 for circularand noncircular heads and covers bolted to the shell, flange,or side plate as indicated in the figures. Note that eq. (2)or (5) shall be used because of the extra moment appliedto the cover by the bolting. When the cover plate is groovedfor a peripheral gasket, as shown in illustration (k) the netcover plate thickness under the groove or between the

25

groove and the outer edge of the cover plate shall be notless than

d� 1.9Whg /Sd3

for circular heads and covers, not less than

d� 6Whg /SLd2

for noncircular heads and covers.Fig. PG-31, illustrations (m), (n), and (o): C p 0.3 for

a circular plate inserted into the end of a shell, pipe, orheader and held in place by a positive mechanical lockingarrangement, and when all possible means of failure eitherby shear, tension, compression, or radial deformation,including flaring, resulting from pressure and differentialthermal expansion, are resisted with a factor of safety ofat least 4. Seal welding may be used, if desired.

Fig. PG-31, illustration (p): C p 0.25 for circular andnoncircular covers bolted with a full-face gasket to shell,flanges, or side plates.

Fig. PG-31, illustration (q): C p 0.75 for circular platesscrewed into the end of a shell, pipe, or header having aninside diameter d not exceeding 12 in. (300 mm); or forheads having an integral flange screwed over the end of ashell, pipe, or header having an inside diameter d notexceeding 12 in. (300 mm); and when the design of thethreaded joint against failure by shear, tension, compres-sion, or radial deformation, including flaring, resultingfrom pressure and differential thermal expansion, is basedon a factor of safety of at least 4. If a tapered pipe threadis used, the requirements of Table PG-39 shall be met.Seal welding may be used, if desired.

Fig. PG-31, illustration (r): C p 0.33 for circular plateshaving a dimension d not exceeding 18 in. (450 mm)inserted into the shell, pipe, or header and welded as shown,and otherwise meeting the requirements for welded boilerdrums including postweld heat treatment but omitting volu-metric examination. The end of the shell, pipe, or headershall be crimped over at least 30 deg, but not more than45 deg. The crimping may be done cold only when thisoperation will not injure the metal. The throat of the weldshall be not less than the thickness of the flat head or theshell, pipe, or header, whichever is greater.

Fig. PG-31, illustration (s): C p 0.33 for circular beveledplates having a diameter, d, not exceeding 18 in. (450 mm)inserted into a shell, pipe, or header, the end of which iscrimped over at least 30 deg, but not more than 45 deg,and when the undercutting for seating leaves at least 80%of the shell thickness. The beveling shall be not less than75% of the head thickness. The crimping shall be donewhen the entire circumference of the cylinder is uniformlyheated to the proper forging temperature for the materialused. For this construction, the ratio ts /d shall be not less



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2010 SECTION I

than the ratio P/S nor less than 0.05. The maximum allow-able working pressure for this construction shall not exceedPp5S/d (Pp125S/d).

OPENINGS AND COMPENSATION16

PG-32 OPENINGS IN SHELLS, HEADERS,AND DISHED HEADS

PG-32.1 The rules for openings and compensation inPG-32 through PG-39 shall apply to all openings in shells,headers, and dished heads except as otherwise provided inPG-29.3, PG-29.7, PG-29.12, PG-32.1.2, PG-32.1.4,PG-32.1.5, and PFT-40.

PG-32.1.1 The notations used throughout PG-32.1are defined as follows:

A, B p the finished opening diameters of any two finishedopenings under consideration, in. (mm) (see dbelow)

D p the outside diameter of the shell, header, or dishedhead containing the opening, in. (mm)

d p diameter of a finished opening, in. (mm) (seePG-33.3)

dmax. p the maximum permissible finished opening diam-eter for an uncompensated opening, in. (mm) (seePG-32.1.2)

K p PD /1.82 St (where K shall not exceed 0.990)Lh p the distance between centers of the two openings

measured on the surface of the dished headLs p the distance between centers of the two openings

measured on the surface of the shell or headerP p the maximum allowable working pressureS p the maximum allowable stress value, taken from

Tables 1A and 1B of Section II, Part Dt p the nominal thickness of the head, shell, or header,

in. (mm)X p the limits of compensation parallel to the vessel

wall (see PG-36.2)

PG-32.1.2 Groups of openings may be designed inaccordance with the rules for ligaments in PG-52 or PG-53,provided the diameter of the largest finished opening withinthe group does not exceed that permitted by the following:

(U.S. Customary Units)

dmax. p 2.75 [Dt (1 − K)]1/3

(SI Units)dmax. p 8.08 [Dt (1 − K)]1/3

16 The rules governing openings as given in this Code are based onthe stress intensification created by the existence of a hole in an otherwisesymmetrical section. They are based on experience with vessels designedwith safety factors of 4 and 5 applied to the specified minimum tensilestrength of the shell material. External loadings such as those due tothermal expansion or to unsupported weight of connecting piping havenot been evaluated. These factors should be given attention in unusualdesigns or under conditions of cyclic loading.

26

Multiple openings that are not designed as ligaments shallcomply with PG-38.

PG-32.1.3 Single Openings. Single openings aredefined as openings that have a minimum center-to-centerdistance between adjacent openings not less than Lh or Ls,where

Lh pA + B

2(1 − K)and Ls p 2X

PG-32.1.4 Openings in Shells and Headers. No cal-culation need be made to determine the availability ofcompensation for a single opening, not covered by PG-38,PG-52, or PG-53 in shells or headers when the diameterof the finished opening, d, as defined in PG-33.3 does notexceed the larger of either

(a) one-fourth the inside diameter of the shell or header,nor 23⁄8 in. (60 mm), or

(b) the value of dmax. calculated in PG-32.1.2 for singleopenings not addressed in (a) above.

PG-32.1.5 Openings in Dished Heads. No calcula-tion need be made to determine the availability of compen-sation for a single opening in dished heads under the sameconditions stipulated for openings in shells and headers inPG-32.1.4, provided the following additional requirementsare met.

PG-32.1.5.1 The openings shall be located com-pletely within the center portion of a dished head boundedby the tangent line between the spherically dished portionand the knuckle radius, but not closer than the thicknessof the head to the edge of this circle or to a flanged-inmanway. For a 2:1 ellipsoidal head, the opening shall belocated completely within the center portion of the headbounded by a circle equal to 80% of the inside diameter,but not closer than the thickness of the head to the edgeof this circle.

PG-32.1.5.2 For dished heads other thanfull-hemispherical heads, the maximum allowable openingdiameter shall not exceed that permitted in PG-32.1.4 foran equivalent shell constructed of the same material, havingthe same outside diameter as the flange of the head, and thesame maximum allowable working pressure as the head.

PG-32.1.5.3 For full-hemispherical heads, themaximum allowable opening diameter shall not exceedthat permitted in PG-32.1.4 for an equivalent shell con-structed of the same material, having the same outsidediameter as the flange of the head, and the same maximumallowable working pressure as the head; where the valueof K used in the calculations of PG-32.1.2 shall be one-halfthe value calculated by the equation in PG-32.1.1.



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2010 SECTION I

PG-32.2 Shape of Openings17

PG-32.2.1 Openings in cylindrical portions of ves-sels or in formed heads shall preferably be circular, ellip-tical, or obround.18

When the long dimension of an elliptical or obroundopening exceeds twice the short dimension, the compensa-tion across the short dimension shall be increased as neces-sary to provide against excessive distortion due to twistingmoment.

PG-32.2.2 Openings may be of other shapes thanthose given in PG-32.2.1, and all corners shall be providedwith a suitable radius. When the openings are of suchproportions that their strength cannot be computed withassurance of accuracy, or when doubt exists as to the safetyof a vessel with such openings, the part of the vesselaffected shall be subjected to a proof hydrostatic test asprescribed in PG-18.

PG-32.3 Size of Openings

PG-32.3.1 Properly reinforced openings in cylindri-cal and spherical shells are not limited as to size andshall comply with the provisions that follow, and with theadditional provisions given under PG-32.3.2.

PG-32.3.2 The rules given herein for compensationapply to openings not exceeding the following dimensions:

(a) for vessels 60 in. (1 500 mm) in diameter and less,1⁄2 the vessel diameter but not over 20 in. (500 mm)

(b) for vessels over 60 in. (1 500 mm) in diameter, 1⁄3the vessel diameter but not over 40 in. (1 000 mm)

PG-32.3.3 Larger openings should be given specialattention and may be provided with compensation in anysuitable manner that complies with the intent of the Coderules. It is recommended that the compensation providedbe distributed close to the opening. (A provision of abouttwo-thirds of the required compensation within a distanceof one-fourth of the nozzle diameter on each side of thefinished opening is suggested.) Special considerationshould be given to the fabrication details used and theinspection employed on critical openings; compensationoften may be advantageously obtained by use of a thickershell plate for a vessel course or inserted locally aroundthe opening; welds may be ground to concave contour andthe inside corners of the opening rounded to a generousradius to reduce stress concentrations. Appropriate prooftesting may be advisable in extreme cases of large openingsapproaching full vessel diameter, openings of unusualshape, etc.

17 The opening made by a pipe or a circular nozzle, the axis of whichis not perpendicular to the vessel wall or head, may be considered anelliptical opening for design purposes.

18 An obround opening is one which is formed by two parallel sidesand semicircular ends.

27

PG-33 COMPENSATION REQUIREDFOR OPENINGS IN SHELLSAND DISHED HEADS

PG-33.1 General. The rules in this subparagraph applyto all openings other than flanged-in openings in dishedheads covered by PG-29.3, PG-29.7, and PG-29.12; open-ings in flat heads covered by PG-35; and openings coveredwithin PG-32.1.2, PG-32.1.4, and PG-32.1.5.

When required, compensation shall be provided in suchamount and distribution that the requirements for area ofcompensation are satisfied for all planes through the centerof the opening and normal to the vessel surface. For acircular opening in a cylindrical shell, the plane containingthe axis of the shell is the plane of greatest loading due topressure.

PG-33.2 Area Required. The total cross-sectional areaof compensation required in any given plane for a vesselunder internal pressure shall be not less than A, as definedin Fig. PG-33.1.

PG-33.3 The notation used in this paragraph is definedas follows:

d p diameter in the plane under consideration of thefinished opening (see Fig. PG-33.2)

p the maximum diameter of the threads, in the planeunder consideration, in the finished opening, forinside tapped NPT fittings

Dp p outside diameter of reinforcing element (Theactual size of reinforcing element may exceedthe limits of reinforcement established by PG-36;however, credit cannot be taken for any materialoutside these limits.)

F p factor from PG-33 and Fig. PG-33.3, which com-pensates for the variation in pressure stresses ondifferent planes with respect to the longitudinalaxis of a cylindrical shell. F p 1.0 for formed orflat heads.

fr p strength reduction factor, not greater than 1.0 (seeFig. PG-33.1)

fr1 p Sn /Sv for nozzle wall inserted through the vesselwall

fr2 p (lesser of Sn or Sp) /Sv

fr3 p SP/Sv

h p distance nozzle projects inward from the outersurface of the vessel wall (Extension of the nozzlebeyond the inside surface of the vessel wall is notlimited; however, for reinforcement calculations,credit shall not be taken for material outside thelimits of reinforcement established by PG-36.)

Rn p inside radius of the nozzle under considerationS p allowable stress value in tension (from Tables 1A

and 1B of Section II, Part D)Sn p allowable stress in nozzle (see S)



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2010 SECTION I

FIG. PG-33.1 NOMENCLATURE AND FORMULAS FOR REINFORCED OPENINGS

Area required

Area available in shell: use larger value

Area available in nozzle projecting outward; use smaller value

Area available in nozzle projecting inward

Area available in outward nozzle weld

Area available in inward nozzle weld

Area available in outer element weld

Area available in element [Note (1)]

With reinforcing element added:

2.5t or 2.5tnUse smaller value

2.5t or 2.5tn + teUse smaller value

tr

trn

te

Rntn

Dp

WL2

WL3

h

WL1

t

d

d or Rn + tn + t

Use larger value

See PG-36 for limits of reinforcement

d or Rn + tn + t

Use larger value

For nozzle wall inserted through the vessel wall For nozzle wall abutting the vessel wall

Notes for set through nozzles, Aextends to the nozzle O.D.

= A1

= A = (d + 2tn)trF

= A3 = 2tnfr1h

= A41 = (WL1)2fr2

= A43 = (WL3)2fr1

= A42 = (WL2)2fr3

= A5 = (Dp – d – 2tn)tefr3

A42 = (WL2)2fr3

A5 = (Dp – d – 2tn)tefr3

If A1 +A2 + A3 + A41 + A43 A Opening is adequately reinforced

= (d – 2tn)(t – Ftr)

= 2t (t – Ftr)

= A2 = 2(tn – trn)(21/2tfr1)

= 2(tn – trn)(21/2tn + te)fr1

A1

A = dtrF

A3 = 0

A41 = (WL1)2fr2

A43 = 0

= d(t – Ftr )

= 2(t + tn)(t – Ftr )

A2 = 2(tn – trn)(21/2tfr1)

= 2(tn – trn)(21/2tn + te)fr1

If A1 +A2 + A3 + A41 + A42 + A43 + A5 A Opening is adequately reinforced

If A1 +A2 + A3 + A41 + A43 A Opening is not adequately reinforced so reinforcing elements must be added and /or thickness must be increased

GENERAL NOTES:(a) This figure illustrates common nozzle configurations and is not intended to prohibit other configurations permitted by the Code.(b) See PG-33.3 and PG-36 for definitions of nomenclature.

NOTE:(1) This formula is applicable for a rectangular cross-sectional element that falls within the limits of reinforcement.

28



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2010 SECTION I

FIG. PG-33.2 SOME REPRESENTATIVE CONFIGURATIONS DESCRIBING THE DIMENSIONS te, h, and d

tn = 0h = 0

tn

te tetet

t

t

(a) (b)

d

d30 deg min.

60 deg

(d)

d

tntn

(c)

h

d

t

tet

d

(f)

tn

13

tet

d

(i)

tn

3/4 in (19 mm) R min.

te = 0.732 R

tete

t

t

d

(h)(g)

tn

60 deg60 deg30

deg max.

45 deg max.d

tn

tete = 0

t

d

30 deg

(e–1) (e–2)(e)

tn

tn

t

d

tx

t

L

d

h

30 deg min.

GENERAL NOTES: Use illustration (e) to determine whether illustration (e-1) or (e-2) applies:(a) If L < 2.5 tx, use illustration (e-1).(b) If L ≥ 2.5 tx, use illustration (e-2).(c) The 30 deg min. transition shown at illustration (e) is typical for illustrations (e-1) and (e-2).

29



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2010 SECTION I

FIG. PG-33.3 CHART FOR DETERMININGVALUE OF F

1.00

0.95

0.90

0.85

0.80

0.75

0.70

0.65

0.60

0.55

Angle with plane with longitudinal axis, deg

Valu

e o

f F

0 10 20 30 40 50 60 70 80 900.50

GENERAL NOTE: F p 1 − 0.5 sin2 �

SP p allowable stress in reinforcing element (plate)(see S)

Sv p allowable stress in vessel (see S)t p thickness of the vessel wall

te p thickness of attached reinforcing pad or height ofthe largest 60 deg right triangle supported by thevessel and nozzle outside diameter projected sur-faces and lying completely within the area of inte-gral reinforcement (see Fig. PG-33.2)

tn p nominal thickness of nozzle walltr p required thickness of a seamless shell or head

computed by the rules of the Code for the desig-nated pressure, except when

(a) the opening and its compensation are ina torispherical head and are entirely within thespherical portion; tr is the thickness required fora seamless hemispherical head of the same radiusas that of the spherical portion

(b) the opening and its compensation are in anellipsoidal head in which one-half of the minoraxis is equal to one-fourth of the inside diameter,

30

and are located entirely within a circle the centerof which coincides with the center of the headand the diameter of which is equal to 80% of theshell inside diameter, tr is the thickness requiredfor a seamless hemispherical head of radius equalto 90% of the inside diameter of the shell

trn p required thickness of seamless nozzle wall; foundby the formula used for tr for the shell, omittingthe C factor (The value of S used in determiningtrn shall be based on the nozzle material). Thevalue of trn shall be taken as zero for the entirewall of manhole and handhole rings projectinginternally with the cover on the inside.

PG-34 FLANGED-IN OPENINGS INFORMED HEADS

PG-34.1 All openings in torispherical, ellipsoidal, andhemispherical heads shall be provided with reinforcementin accordance with PG-33, except for heads that meet therequirements in PG-34.2 and PG-29.3, PG-29.7, andPG-29.12.

PG-34.2 A flanged-in manhole opening in a dishedhead shall be flanged to a depth of not less than three timesthe required thickness of the head for plate up to 11⁄2 in.(38 mm) in thickness. For plate exceeding 11⁄2 in. (38 mm)in thickness, the depth shall be the thickness of the plateplus 3 in. (75 mm). The depth of flange shall be determinedby placing a straight edge across the outside opening alongthe major axis and measuring from the straight edge to theedge of the flanged opening. A manhole opening may becompensated by a manhole ring or other attachment inplace of flanging in accordance with PG-33.

PG-35 COMPENSATION REQUIRED FOROPENINGS IN FLAT UNSTAYEDHEADS AND FLAT STAYED PLATES

PG-35.1 General. The rules in this paragraph apply toall openings other than small openings covered byPG-32.1.4.

PG-35.2 Flat unstayed heads that have an openingwith a diameter that does not exceed one-half of the headdiameter or shortest span, as defined in PG-31, shall havea total cross-sectional area of compensation not less than0.5 times the required area specified in PG-33.2.

As an alternative, the thickness may be increased toprovide the necessary openings compensation as specifiedin PG-35.2.1 and PG-35.2.2

PG-35.2.1 By using 2C or 0.75 in place of C, which-ever is less, in eq. (1) or (3) for calculating head thicknessin PG-31.3 or



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2010 SECTION I

PG-35.2.2 In eq. (2) or (5) by doubling the quantityunder the square root sign.

PG-35.3 Flat unstayed heads that have an opening witha diameter that exceeds one-half of the head diameter orshortest span, as defined in PG-31.3, shall be designed asprovided in PG-16.1.

PG-35.4 Openings in flat stayed plates such aswaterlegs and tubesheets of firetube boilers shall have atotal cross-sectional area of compensation not less than0.5dt, where

d p for circular openings, the diameter of the finishedopening; for elliptical openings, the major axisof the finished opening; or for other shapes, themaximum span

t p the required thickness for the stayed surface calcu-lated in accordance with PG-46 using the maxi-mum distance between stays, tubes, or othersupport in the area where the opening resides

PG-36 LIMITS OF METAL AVAILABLEFOR COMPENSATION

PG-36.1 The boundaries of the cross-sectional area inany plane normal to the vessel wall and passing throughthe center of the opening within which area metal mustbe located in order to have value as compensation aredesignated as the limits of compensation for that plane(see Fig. PG-33.1).

PG-36.2 The limits of compensation, measured parallelto the vessel wall, shall be at a distance, on each side ofthe axis of the opening, equal to the greater of the following:

PG-36.2.1 The diameter of the finished opening.

PG-36.2.2 The radius of the finished opening plusthe thickness of the vessel wall, plus the thickness of thenozzle wall.

PG-36.3 The limits of compensation, measured normalto the vessel wall, shall conform to the contour of thesurface at a distance from each surface equal to the smallerof the following:

PG-36.3.1 21⁄2 times the nominal shell thickness.

PG-36.3.2 21⁄2 times the nozzle-wall thickness plusthe thickness of any added compensation, exclusive ofweld metal on the side of the shell under consideration.

PG-36.4 Metal within the limits of reinforcement thatmay be considered to have reinforcing value shall includethe following:

PG-36.4.1 Metal in the vessel wall over and abovethe thickness required to resist pressure. The area of thevessel wall available as compensation is the larger of thevalues of A1 given by the formulas shown in Fig. PG-33.1.

31

PG-36.4.2 Metal over and above the thicknessrequired to resist pressure in that part of a nozzle wallextending outside the vessel wall. The maximum area inthe nozzle wall available as compensation is the smallerof the values of A2 given by the formulas shown in Fig.PG-33.1.

All metal in the nozzle wall extending inside the vesselwall may be included. No allowance shall be taken for thefact that a differential pressure on an inwardly extendingnozzle may cause opposing stress to that of the stress inthe shell around the opening.

PG-36.4.3 Metal added as compensation (continu-ously about the nozzle) when welded to both the vesseland nozzle, and metal provided in attachment welds.

PG-36.5 Typical examples of the application of theabove rules are presented in A-65 through A-69.

PG-37 STRENGTH OF COMPENSATIONPG-37.1 Material used for compensation shall have an

allowable stress value equal to or greater than that of thematerial in the vessel wall, except that material of lowerstrength may be used provided the area of compensation isincreased in inverse proportion to the ratio of the allowablestress values of the two materials to compensate for thelower allowable stress value of the compensation. No creditmay be taken for the additional strength of any compensa-tion having a higher allowable stress value than that of thevessel wall. Deposited weld metal outside of either thevessel wall or any reinforcing pad used as reinforcementshall be credited with an allowable stress value equivalentto the weaker of the materials connected by the weld.Vessel-to-nozzle or pad-to-nozzle attachment weld metalwithin the vessel wall or within the pad may be creditedwith a stress value equal to that of the vessel wall or pad,respectively.

PG-37.2 The welds that attach elements of compensa-tion that are not an integral part of the vessel wall shallhave a strength, W, not less than the load carried by thoseelements defined as follows:

W p (A − A1) Sv

where A, A1, and Sv are defined in PG-33.3 and Fig. PG-33.1.

PG-37.3 When a reinforcing pad is required by therules of PG-33, the welds attaching the nozzle to the padand shell shall be checked independently to assure that theloads carried by the individual elements can be transmittedby the attaching welds. For detailed requirements andexamples of calculating the strength of welds, see PW-15.

PG-37.4 Welds attaching elements of compensationneed not satisfy the weld strength requirements of PG-37.2under the following circumstances:



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(10)

2010 SECTION I

(a) openings that are exempt in PG-32 from compensa-tion calculations

(b) openings designed by ligaments rules of PG-52 andPG-53 and/or

(c) openings with elements of compensation attachedby full penetration welds as listed in PW-15.1.6

PG-37.5 The minimum weld sizes shall not be smallerthan the minimum required by PW-16.

PG-38 COMPENSATION FORMULTIPLE OPENINGS

PG-38.1 When any two adjacent openings that requirecompensation are spaced at less than two times the distancedefined in PG-36.2 so that their limits of compensationoverlap, the two openings (or similarly for any larger groupof openings) shall be compensated in accordance withPG-33 with a compensation that has an area equal to thecombined area of the compensation required for the sepa-rate openings. No portion of the cross section shall beconsidered as applying to more than one opening, or beevaluated more than once in a combined area.

PG-38.2 Two adjacent openings shall have a distancebetween centers not less than 11⁄3 times their averagediameter.

PG-38.3 When a group of openings is provided withcompensation by a thicker section buttwelded into the shellor head, the edges of the inserted section shall be taperedas prescribed in PW-9.3.

PG-38.4 When a shell or drum has a series of holesin a definite pattern, the net cross-sectional area betweenany two finished openings within the limits of the actualshell wall, excluding the portion of the compensation notfused to the shell wall, shall equal at least 0.7F of thecross-sectional area obtained by multiplying the center-to-center distance of the openings by the required thicknessof a seamless shell, where the factor F is taken from Fig.PG-33.3 for the plane under consideration (see Fig. PG-38).

PG-39 METHODS OF ATTACHMENT OFPIPE AND NOZZLE NECKS TOVESSEL WALLS

PG-39.1 General. Except as limited in PG-32, nozzlesmay be attached to the shell or head of a vessel by any ofthe methods of attachment given in this paragraph.

PG-39.2 Welded Connections. Attachment by weldingshall be in accordance with the requirements of PW-15and PW-16.

PG-39.4 Studded Connections. Connections may bemade by means of bolt studs. The vessel shall have a flat

32

FIG. PG-38 ILLUSTRATIONS OF THE RULE GIVEN INPG-38.4

trt

56

7

14 3

2

8

trt

56

7

14 3

2

8

trt

56

7

14 3

2

8

GENERAL NOTE: The cross-sectional area represented by 5, 6, 7,and 8 shall be at least equal to the area of the rectangle representedby 1, 2, 3, and 4 multiplied by 0.7F, in which F is a value from Fig.PG-33.3 and tr is the required thickness of a seamless shell.

surface machined on the shell, or on a built-up pad, or ona properly attached plate or fitting. Drilled holes to betapped for straight threads shall not penetrate within one-fourth of the wall thickness from the inside surface of thevessel, unless at least the minimum thickness required asabove is maintained by adding metal to the inside surfaceof the vessel. Where tapped holes are provided for studs,the threads shall be full and clean and shall engage thestud for a length not less than the larger of ds or

0.75ds �

Maximum allowable stress value ofstud material at design temperatureMaximum allowable stress value of

tapped material at design temperature

in which ds is the diameter of the stud, except that thethread engagement need not exceed 11⁄2ds. Studded connec-tions shall meet the requirements for compensation. Nocredit for compensation shall be allowed for any areasattached by studs only.

PG-39.5 Threaded ConnectionsPG-39.5.1 Where a threaded connection is to be

made to a boiler component it shall be into a threadedhole. The threads shall conform to the requirements ofASME B1.20.1 and provide for the pipe to engage the



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2010 SECTION I

TABLE PG-39MINIMUM NUMBER OF THREADS PER CONNECTION

U.S. Customary Units

Pressure up to and including 300 psi

Size of pipe connection (NPS) . . . 1 & 11⁄4 11⁄2 & 2 21⁄2 to 4 5 & 6 8 10 12Threads engaged . . . 4 5 7 8 10 12 13Min. plate thickness required, in. . . . 0.348 0.435 0.875 1.0 1.25 1.5 1.625

Pressures above 300 psi

Size of pipe connection, (NPS) 1⁄2 & 3⁄4 1 to 11⁄2 2 21⁄2 & 3 4 to 6 8 10 12Threads engaged 6 7 8 8 10 12 13 14Min. plate thickness, required, in. 0.43 0.61 0.70 1.0 1.25 1.5 1.62 1.75

SI Units

Pressure up to and including 2 MPa

Size of pipe connection (DN) . . . 25 & 32 40 & 50 65 to 100 125 & 150 200 250 300Threads engaged . . . 4 5 7 8 10 12 13Min. plate thickness required (mm) . . . 9 11 22 25 32 38 41

Pressures above 2 MPa

Size of pipe connection (DN) 15 & 20 25 to 40 50 65 & 80 100 to 150 200 250 300Threads engaged 6 7 8 8 10 12 13 14Min. plate thickness, required (mm) 11 16 18 25 32 38 41 44

minimum number of threads specified in Table PG-39 afterallowance has been made for curvature of the vessel wall.A built-up pad or properly attached plate or fitting may beused to provide the metal thickness and number of threadsrequired in Table PG-39, or to furnish compensation whenrequired.

PG-39.5.2 Threaded joints for boiler connections forexternal piping shall be in accordance with the followingsize and pressure limitations and shall not be used wherethe temperature exceeds 925°F (495°C).

Maximum MaximumSize, NPS (DN) Pressure, psi (MPa)

3 (80) 400 (3)2 (50) 600 (4)1 (25) 1,200 (8)

3⁄4 (20) and smaller 1,500 (10)

PG-39.5.3 Threaded connections for plug closuresused for inspection openings, end closures, and similarpurposes may be used within the size and pressure limita-tions of Table PG-39.

PG-39.6 Expanded Connections. Provided therequirements for compensation are met, a pipe, tube, orforging not exceeding 6 in. (150 mm) in outside diametermay be attached to shells, heads, headers, or fittings byinserting through an opening and expanding in accordancewith the rules for tube attachment in Parts PWT and PFT,whichever is applicable.

The sharp edges left in drilling tube holes shall beremoved on both sides of the plate with a file or other tool.

33

The inner surface of the tube hole in any form of attachmentmay be grooved or chamfered.

PG-39.7 All welded connections shall be postweld heattreated after attachment unless specifically allowedotherwise.

PG-42 GENERAL REQUIREMENTS FORFITTINGS, FLANGES, AND VALVES

PG-42.1 Applicable ASME Standards. Except whensupplied as miscellaneous pressure parts under the provi-sions of PG-11, all fittings, flanges, and valves shall meetthe requirements of the following ASME Standards, includ-ing the restrictions contained within the standards, and anynoted as part of this Code. The product standard establishesthe basis for pressure–temperature rating and marking.

PG-42.1.1 ASME B16.1, Cast Iron Pipe Flanges andFlanged Fittings19

PG-42.1.3 ASME B16.3, Malleable Iron ThreadedFittings, Classes 150 (PN 20) and 300 (PN 50)

PG-42.1.4 ASME B16.4, Gray Iron Threaded Fit-tings

PG-42.1.5 ASME B16.5, Pipe Flanges and FlangedFittings (see PG-42.2)

PG-42.1.5.1 Pressure–Temperature Ratings perTable 2

19 Classes 25 and 800 are not applicable to Section I.



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2010 SECTION I

PG-42.1.5.2 Facing Dimensions (other than ring-joint) per Table 4

PG-42.1.5.3 Facing Dimensions for Ring-JointFlanges per Table 5

PG-42.1.5.4 Dimensions of Flanges for PressureRating Classes per Tables 8 through 28

PG-42.1.6 ASME B16.9, Factory-Made WroughtSteel Buttwelding Fittings

When pressure ratings are established under the provi-sions of para. 2.1 of ASME B16.9 they shall be calculatedas for straight seamless pipe in accordance with ASMEB31.1. Parts such as lap-joint stub ends fabricated by weld-ing with filler metal added may not be used in Code Con-struction, unless they are fabricated in accordance withPG-11.3.

PG-42.1.7 ASME B16.11, Forged Fittings, Socket-Welding and Threaded (see PG-42.2)

PG-42.1.8 ASME B16.15, Cast Copper AlloyThreaded Fittings, Classes 125 and 250 (see PG-8.4 andPG-42.4.11)

PG-42.1.9 ASME B16.20, Metallic Gaskets for PipeFlanges: Ring-Joint, Spiral-Wound, and Jacketed

PG-42.1.10 ASME B16.24, Cast Copper Alloy PipeFlanges and Flanged Fittings (see PG-8.4)

PG-42.1.11 ASME B16.25, Buttwelding Ends

PG-42.1.12 ASME B16.34, Valves — Flanged,Threaded, and Welding End (see PG-42.2 and PG-42.4.3)

PG-42.1.14 ASME B16.42, Ductile Iron PipeFlanges and Flanged Fittings, Classes 150 (PN 20) and300 (PN 50) (see PG-8.3)

PG-42.2 Marking. All valves and fittings shall bemarked with the name, trademark, or other identificationof the manufacturer and the primary service pressure ratingexcept that the pressure rating marking may be omittedfrom:

PG-42.2.1 Cast iron threaded fittings for Class 125(PN 20) working pressure

PG-42.2.2 Malleable iron threaded fittings for Class150 (PN 20) working pressure

PG-42.2.3 Nonferrous threaded fittings for Classes125 (PN 20) and 250 (PN 50) working pressure

PG-42.2.4 Cast iron and nonferrous companionflanges

PG-42.2.5 Additional markings for buttwelding fit-tings, as called for by several Code Standards for all valvesand fittings, are recommended if the size and shape of thevalve or fitting permit.

PG-42.3 Flange Materials. Flanges shall be made ofmaterials permitted by this Section or of materials specifi-cally listed in the applicable product standards listed in

34

PG-42.1, but not of materials specifically prohibited orbeyond the use limitations listed in this Section. Rolled orforged flanges may be made from material conforming toany forging specification among these permitted materials,except that SA-181 shall not be used for flanges whosepressure rating is higher than Class 300 (PN 50). Hub-typeflanges shall not be cut or machined from plate material.

PG-42.4 Additional Requirements. Flanges made ofother materials permitted under this Section shall be atleast equal to the strength requirements, and the facingdimensions and bolt circles shall agree with the Standardotherwise required.

PG-42.4.1 The thickness of all fitting and valve bod-ies subject to pressure shall be not less than that requiredby the applicable ASME Standard listed in PG-42.1 forthe corresponding maximum allowable working pressureand temperature for the material used. The cylindrical endsof cast steel welding end valves and fittings conformingto ASME B16.5 or B16.34 may be proportioned with acasting quality factor of 100% provided these areas arefinish-machined both inside and outside, are carefullyinspected, and that the contour of the welding end transitioncomplies with PG-42.4.2.

PG-42.4.2 The welding ends of component bodiessuch as fittings and valves, whether constructed of castproducts, wrought products, or any other fabrication pro-cess acceptable under the Code, shall provide a gradualchange in thickness from that of the adjoining pipe to thatof the component body. Any configuration of weld endtransition that lies entirely within the envelope shown inFig. PG-42.1 is acceptable, provided that

(a) the wall thickness in the transition region is not lessthan the smaller of the fitting or valve thickness requiredby PG-42.4.1 or the minimum value of the pipe thicknesstmin defined under Fig. PG-42.1.

(b) the transition region including the weld joint shallavoid sharp reentrant angles and abrupt changes in slope.When the included angle between any two adjoining sur-faces of a taper transition is less than 150 deg, the intersec-tion or corner (except for the weld reinforcement) shall beprovided with a radius of at least 0.05tmin.

The configurations and tolerances suggested by suchweld end standards as ASME B16.9 and ASME B16.25are acceptable only to the extent that the resulting productand weld joint will comply with these requirements ofPG-42.4.2. In Fig. PG-42.1 the thickness in the plane atthe end of the fitting or valve shall not be less than tmin

and shall not exceed a maximum of either: the greater of[tmin + 0.15 in. (4 mm)] or 1.15tmin when ordered on aminimum wall basis, or the greater of [tmin + 0.15 in.(4 mm)] or 1.10tnom when ordered on a nominal wall basis.

PG-42.4.3 Fittings in which there are minor changesin the center-to-face dimensions or in which the angles of



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2010 SECTION I

FIG. PG-42.1 WELDING END TRANSITIONS MAXIMUM ENVELOPE

See Note (1)

Maximum–See Note (2)

Minimum–1.0tmin.

Transition Region

GENERAL NOTES:(a) Weld bevel is shown for illustration only.(b) The weld reinforcement permitted by PW-35 may be outside the maximum envelope.

NOTES:(1) The value of tmin. is whichever of the following is applicable: (a) the minimum ordered wall thickness of the pipe; or (b) the minimum ordered wall thickness of the tube; or (c) 0.875 times the nominal wall thickness of pipe ordered to a pipe schedule wall thickness that has an undertolerance of 12.5%; or (d) the minimum ordered wall thickness of the cylindrical welding end of a component or fitting (or the thinner of the two) when the joint is between two components.(2) The maximum thickness at the end of the component is: (a) the greater of [tmin.+ 0.15 in. (4mm)] or 1.15tmin. when ordered on a minimum wall basis; (b) the greater of [tmin.+ 0.15 in. (4mm)] or 1.10tnom. when ordered on a nominal wall basis.

Radius of at least 0.05tmin.

30 deg maximum

Component or Fitting

30 deg maximum

45 deg maximum

Radius of at least 0.05tmin.

11/2 tmin.

tmin.

Radius not mandatory

Maximum slope 1:3

2tmin.

tnom. tmin.

2

Outside

Inside

35



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2010 SECTION I

elbows differ from those given in an ASME Standard inPG-42.1 may be considered to fall within the scope of thestandard provided the other requirements for materials,dimensions, and thickness are met.

PG-42.4.4 Flanges and flanged fittings meeting therequirements of ASME B16.5 or valves meeting therequirements of ASME B16.34 may be used at the pres-sure–temperature ratings established by those standards.Standard Class, Special Class, or Limited Class valves maybe used, provided that all parts of the valves are suitablefor the pressure–temperature conditions at which they areto be used. Valves of intermediate rating or class, asdescribed in ASME B16.34, are permitted.

PG-42.4.5 When the service requirements exceedthe permissible values given in ASME B16.5 or ASMEB16.34, the requirements of the Code will be met if thebolting material, flange thickness, and/or body thicknessare increased so that the deflection limits are no greaterand the factor of safety is no less than that of the nearestPressure Rating Class in ASME B16.5 or ASME B16.34.

PG-42.4.6 Steel buttwelding fittings may be usedprovided they are at least equal to the requirements ofASME B16.9.

PG-42.4.7 ASME Standard slip-on flanges shall notexceed NPS 4 (DN 100). Attachment of slip-on flangesshall be by double fillet welds. The throats of the filletwelds shall not be less than 0.7 times the thickness of thepart to which the flange is attached.

PG-42.4.8 ASME Standard socket welded flangesmay be used in piping or boiler nozzles provided the dimen-sions do not exceed NPS 3 (DN 80) for Class 600 (PN 110)and lower, and NPS 21⁄2 (DN 65) in Classes 900 (PN 150)and 1,500 (PN 260).

PG-42.4.9 Threaded fittings of cast iron or malleableiron conforming to the requirements of the ASME Stan-dards for Classes 125 (PN 20), 150 (PN 20), 250 (PN 50),and 300 (PN 50) pressure may be used except where other-wise specifically prohibited or where flanged fittings arespecifically required. They shall not be used for tempera-tures over 450°F (230°C).

PG-42.4.10 Cast- or forged-steel threaded fittings orvalves that are at least equal to the strength requirementsof the ASME Standard fittings that would otherwise berequired may be used in all cases except where flangedfittings are specifically required.

PG-42.4.11 The casting quality factors given inPG-25 do not apply to ASME Standard cast steel fittingswhose dimensions and ratings are incorporated in the Code.

Bronze threaded or flanged type fittings or valves maybe used provided they are at least equal to the strengthrequirements of ASME B16.1 cast iron fittings that wouldotherwise be required. Bronze threaded fittings may be

36

used if they comply with ASME B16.15. The material shallcomply with PG-8.4 and the allowable working stresses arenot to exceed the values given in Table 1B of Section II,Part D, except as provided in PG-67.7. Bronze shall not beused where steel or other material is specifically required.Threaded type fittings shall not be used where flangedtypes are specified.

PG-43 NOZZLE NECK THICKNESS

The minimum thickness of a nozzle neck (includingaccess openings and openings for inspection) shall not beless than the thickness required for the applicable loadings.Additionally, the minimum thickness of a nozzle neck(except for access openings and openings for inspection)shall be not less than the smaller of the following:

PG-43.1 The minimum required thickness of a seam-less shell or head to which it is attached.

PG-43.2 The minimum wall thickness of standard-wallpipe listed in Table 2 of ASME B36.10M.

PG-44 INSPECTION OPENINGSPG-44.1 All boilers or parts thereof shall be provided

with suitable manhole, handhole, or other inspection open-ings for examination or cleaning, except for special typesof boilers where such openings are manifestly not neededor used.

Specific requirements for access openings in certaintypes of boilers appear in other paragraphs.

An elliptical manhole opening shall be not less than12 in. � 16 in. (300 mm � 400 mm) in size.

A circular manhole opening shall be not less than 15 in.(380 mm) in diameter.

A handhole opening in a boiler drum or shell shall benot less than 23⁄4 in. � 31⁄2 in. (70 mm � 89 mm), but itis recommended that, where possible, larger sizes be used.

Manhole, handhole, inspection, and washout openingsin a shell or unstayed head shall be designed in accordancewith the rules of PG-32 to PG-42.

When a threaded opening is to be used for inspectionor washout purposes, it shall be not less than 1 in. (25 mm)pipe size. The closing plug or cap shall be of nonferrousmaterial except for pressures of over 250 psi (1.7 MPa).

The thread shall be a standard tapered pipe thread, exceptthat a straight thread of equal strength may be used if othersealing surfaces to prevent leakage are provided.

PG-44.2 Manhole and handhole cover plates and yokesshall be of rolled, forged, or cast steel except that forpressures not exceeding 250 psi (1.7 MPa), and/or tempera-tures not exceeding 450°F (230°C), either handhole coverplates or yokes may be made of cast iron complying withSA-278.

(10)



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2010 SECTION I

The strength of all such parts together with the boltsand yokes, if any, shall be proportioned for the service forwhich they are used.

PG-44.3 The minimum width of bearing surface for agasket on a manhole opening shall be 11⁄16 in. (17 mm).No gasket for use on a manhole or handhole of any boilershall have a thickness greater than 1⁄4 in. (6 mm), whencompressed.

PG-46 STAYED SURFACESPG-46.1 The minimum thickness and maximum allow-

able working pressure for stayed flat plates and those partsthat, by these rules, require staying as flat plates with staysor staybolts of uniform diameter symmetrically spaced,shall be calculated by the following equations:

t p p � PSC

(1)

P pt2SC

p2 (2)

where

C p 2.1 for welded stays or stays screwed throughplates not over 7⁄16 in. (11 mm) in thickness withends riveted over

p 2.2 for welded stays or stays screwed throughplates over 7⁄16 in. (11 mm) in thickness with endsriveted over

p 2.5 for stays screwed through plates and fittedwith single nuts outside of plate, or with insideand outside nuts, omitting washers

p 2.8 for stays with heads not less than 1.3 timesthe diameter of the stays screwed through platesor made a taper fit and having the heads formedon the stay before installing them, and not rivetedover, said heads being made to have a true bearingon the plate

p 3.2 for stays fitted with inside and outside nuts andoutside washers where the diameter of washers isnot less than 0.4p and thickness not less than t

P p maximum allowable working pressure, psi (MPa)p p maximum pitch measured between straight lines

passing through the centers of the staybolts in thedifferent rows, which lines may be horizontal andvertical, or radial and circumferential, in. (mm)

S p maximum allowable stress given in Table 1A ofSection II, Part D, psi (MPa)

t p minimum thickness of plate, in. (mm)

PG-46.2 The minimum thickness of plates to whichstays may be applied, in other than cylindrical or sphericalouter shell plates, shall be 5⁄16 in. (8 mm), except for weldedconstruction covered by PW-19.

37

FIG. PG-46.2 ACCEPTABLE PROPORTIONS FORENDS OF THROUGH-STAYS

t

1.0

Not less than 21/2 diameters of bolt as measured on the outside of the threaded portion, but must be 0.4 pitch of stays if C = 3.2

Not less than 1/2t if C = 2.8 or less, and not less than t if C = 3.2

PG-46.3 When two plates are connected by stays andonly one of these plates requires staying, the value of Cshall be governed by the thickness of the plate requiringstaying.

PG-46.4 Acceptable proportions for the ends ofthrough-stays with washers are indicated in Fig. PG-46.2.

PG-46.5 The maximum pitch shall be 81⁄2 in. (215 mm)except that for welded-in staybolts the pitch may be greaterprovided it does not exceed 15 times the diameter of thestaybolt.

For the application of PG-48 and PFT-26, see Fig. A-8.

PG-46.6 Where the staybolting of shells is unsymmetri-cal by reason of interference with butt straps or otherconstruction, it is permissible to consider the load carriedby each staybolt as the area calculated by taking the dis-tance from the center of the spacing on one side of thebolt to the center of the spacing on the other side.

PG-46.7 The ends of stays fitted with nuts shall notbe exposed to the direct radiant heat of the fire.

PG-46.8 Stays exceeding 120 diameters in length shallbe supported at intervals not exceeding 120 diameters, orthe cross-sectional area of the stay shall be increased bynot less than 15% of its required area.

PG-47 STAYBOLTSPG-47.1 The ends of staybolts or stays screwed through

the plate shall extend beyond the plate not fewer than twothreads when installed, after which they shall be rivetedover or upset by an equivalent process without excessivescoring of the plates; or they shall be fitted with threadednuts through which the bolt or stay shall extend. The threadlead of both ends and both plates being stayed shall besynchronized to permit the bolt to be installed withoutstripping the threads. The outside ends of solid staybolts8 in. (200 mm) and less in length, if of uniform diameterthroughout their length, shall be drilled with telltale holesat least 3⁄16 in. (5 mm) in diameter to a depth extending atleast 1⁄2 in. (13 mm) beyond the inside of the plate. If such

(10)



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2010 SECTION I

staybolts are reduced in section between their ends belowtheir diameter at the root of the thread, the telltale holesshall extend at least 1⁄2 in. (13 mm) beyond the point wherethe reduction in section commences. Hollow staybolts maybe used in place of solid staybolts with drilled ends. Solidstaybolts over 8 in. (200 mm) long and flexible stayboltsof either the jointed or ball-and-socket type need not bedrilled. Staybolts used in waterlegs of watertube boilersshall be hollow or drilled at both ends, in accordance withthe requirements above stated, irrespective of their length.All threaded staybolts not normal to the stayed surfaceshall have not less than three engaging threads of whichat least one shall be a full thread, but if the thickness ofthe material in the boiler is not sufficient to give one fullengaging thread, the plates shall be sufficiently reinforcedon the inside by a steel plate welded thereto. Telltale holesare not required in staybolts attached by welding.

PG-47.2 The ends of steel stays upset for threadingshall be fully annealed after upsetting.

PG-47.3 Requirements for welded-in staybolts aregiven in PW-19.

PG-48 LOCATION OF STAYBOLTS

PG-48.2 When the edge of a flat stayed plate is flanged,the distance from the center of the outermost stays to theinside of the supporting flange shall not be greater thanthe pitch of the stays plus the inside radius of the flange.

PG-49 DIMENSIONS OF STAYBOLTS

PG-49.1 The required area of a staybolt at its minimumcross section shall be obtained by dividing the load on thestaybolt, computed in accordance with PFT-26, by theallowable stress value in accordance with Table 1A ofSection II, Part D, and multiplying the results by 1.10.

PG-49.2 The diameter of a screw stay shall be takenat the bottom of the thread or wherever it is of the leastdiameter.

PG-52 LIGAMENTS

PG-52.1 The rules of this paragraph apply to groupsof openings that form a definite pattern in pressure parts.(For patterns not definite, see PG-53.) When the rulesof PG-32.1.2 are satisfied, the efficiency of the ligamentbetween the tube holes shall be determined as follows (seeFig. PG-52.1).

38

PG-52.2 Openings Parallel to Vessel AxisPG-52.2.1 When the pitch of the tubes on every tube

row is equal (as in Fig. PG-52.2), the equation is

E pp − d

p

Example: Pitch of tube holes in the drum as shown in Fig.PG-52.2 p 51⁄4 in. Diameter of tube p 31⁄4 in. Diameterof tube holes p 39⁄32 in.

p − dp

p5.25 − 3.281

5.25

p 0.375 efficiency of ligament

PG-52.2.2 When the pitch of the tube holes on anyone row is unequal (as in Fig. PG-52.3 or Fig. PG-52.4),the equation is

E pp1 − nd

p1

Example: Spacing shown in Fig. PG-52.3. Diameter oftube holes p 39⁄32 in.

p1 − ndp1

p12 − 2 � 3.281

12


Example: Spacing shown in Fig. PG-52.4. Diameter oftube holes p 39⁄32 in.

p1 − ndp1

p29.25 − 5 � 3.281

29.25


PG-52.3 Openings Transverse to Vessel Axis. Thestrength of those ligaments between the tube holes that aresubjected to a longitudinal stress shall be at least one-halfthe required strength of those ligaments that come betweenthe tube holes that are subjected to a circumferential stress.

PG-52.4 Holes Along a Diagonal. When a shell ordrum is drilled for tube holes as shown in Fig. PG-52.5,the efficiency of these ligaments shall be that given by thediagram in Fig. PG-52.1. The abscissa (p − d) /p and theratio p′ /p shall be computed. With these values the effi-ciency may be read off the ordinate. Should the point fallabove the curve of equal efficiency for the diagonal andlongitudinal ligaments, the longitudinal ligaments will bethe weaker, in which case the efficiency is computed fromthe following equation:

p − dp

(1)



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

FIG. PG-52.1 DIAGRAM FOR DETERMINING THE EFFICIENCY OFLONGITUDINAL AND DIAGONAL LIGAMENTS BETWEEN

OPENINGS IN CYLINDRICAL SHELLS

20

20 30 40 50 60 70 80 90

30

0.55

40

50

60

70

80

90

0.95

0.90

0.85

0.80

0.75

0.65

0.60

Cir

cum

fere

nti

al p

itch

d

p

p'

Curve o

f Conditi

on of E

qual Effi

ciency

of D

iagonal

and Lo

ngitudin

al Lig

amen

ts

Curv

e of

Con

ditio

n of

Equ

al E

ffici

ency

of D

iago

nal a

nd C

ircum

fere

ntia

l Lig

amen

ts

0.95

0.90

0.85

0.80

0.75

0.70

0.65

0.60

p = longitudinal pitchp' = diagonal pitch

Point ARatio

s of

p'

÷ p

Point B

Longitudinal Efficiency, %

p - dp × 100

Eq

uiv

alen

t Lo

ng

itu

din

al E

ffic

ien

cy o

f D

iag

on

al L

igam

ent,

%

0.70

DrumAxis

GENERAL NOTES:(a) Equations are provided for the user’s option in Notes (b), (c), and (d) below. The use of these equations is permitted for values beyond those

provided by Fig. PG-52.1.

(b) Diagonal efficiency, % pJ + 0.25 − (1 − 0.01Elong)�0.75 + J

0.00375 + 0.005J, where J p (p ′/p1)

2.

(c) Curve of condition of equal efficiency of diagonal and circumferential ligaments,

diagonal efficiency, % p200M + 100 − 2(100 − Elong)�1 + M

(1 + M), where M p [(100 − Elong)/(200 − 0.5Elong)]

2.

(d) Longitudinal efficency, % p Elong p [(p1 − d)/p1] 100.

39



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

FIG. PG-52.2 EXAMPLE OF TUBE SPACING WITHPITCH OF HOLES EQUAL IN EVERY ROW

51/4in.

(133mm)

51/4in.

(133mm)

51/4in.

(133mm)

51/4in.

(133mm)

51/4in.

(133mm)

51/4in.

(133mm)

51/4

(133mm)

Longitudinal Line

in.

FIG. PG-52.3 EXAMPLE OF TUBE SPACING WITHPITCH OF HOLES UNEQUAL IN EVERY SECOND ROW

51/4in.

(133mm)

63/4in.

(171mm)

51/4in.

(133mm)

63/4in.

(171mm)

51/4in.

(133mm)

12 in. (305 mm)

63/4in.

(171mm)

51/4in.

(133mm)

Longitudinal Line

FIG. PG-52.4 EXAMPLE OF TUBE SPACING WITHPITCH OF HOLES VARYING IN EVERY SECOND

AND THIRD ROW

291/4 in. (743 mm)

63/4in.

(171mm)

51/4in.

(133mm)

51/4in.

(133mm)

63/4in.

(171mm)

51/4in.

(133mm)

51/4in.

(133mm)

63/4in.

(171mm)

51/4in.

(133mm)

51/4in.

(133mm)

Longitudinal Line

Example:(1) Diagonal pitch of tube holes in drum as shown

in Fig. PG-52.5 p 6.42 in. Diameter of holes p 41⁄32 in.Longitudinal pitch of tube holes p 111⁄2 in.

p − dp

p11.5 − 4.031

11.5p 0.649 (2)

p ′p

p6.4211.5

p 0.558 (3)

40

FIG. PG-52.5 EXAMPLE OF TUBE SPACING WITHTUBE HOLES ON DIAGONAL LINES

53/4 in.

(146 mm)6.42 in. (163 mm)

Longitudinal Line

The point corresponding to these values is shown at Aon the diagram in Fig. PG-52.1, and the correspondingefficiency is 37.0%. As the point falls below the curve ofequal efficiency for the diagonal and longitudinal liga-ments, the diagonal ligament is the weaker.

(2) Diagonal pitch of tube holes in drum p 635⁄64 in.Diameter of tube holes p 41⁄64 in. Longitudinal pitch oftube holes p 7 in.

p − dp

p7 − 4.0156

7p 0.426 (4)

p ′p

p6.547

7p 0.935

The point corresponding to these values is shown at B onthe diagram in Fig. PG-52.1, and it will be seen that itfalls above the line of equal efficiency for the diagonaland longitudinal ligaments, in which case the efficiency iscomputed from eq. (1). Applying eq. (1), we have

7 − 4.01567

p 0.426, efficiency of ligament, or 42.6%

PG-52.5 When tubes or holes are arranged in a drumor shell in symmetrical groups along lines parallel to theaxis and the same spacing is used for each group, theefficiency for one of the groups shall be not less thanthe efficiency on which the maximum allowable workingpressure is based.

PG-52.6 The symbols defined below are used in theequations of this paragraph

d p diameter of openings, in. (mm)E p efficiency of ligamentp p longitudinal pitch of adjacent openings, in. (mm)p′ p diagonal pitch of adjacent openings, in. (mm)

(10)



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(10)

2010 SECTION I

p1 p pitch between corresponding openings in a seriesof symmetrical groups of openings, in. (mm)

n p number of openings in length p1

The pitch shall be determined at the mean radius of thecylinder.

PG-53 LIGAMENTSPG-53.1 The rules in this paragraph apply to groups

of openings that do not form a definite pattern in pressureparts (For definite patterns, see PG-52.). When the rulesof PG-32.1.2 are satisfied, the efficiency of the ligamentbetween tube holes shall be determined as follows:

PG-53.2 When tubes or holes are unsymmetricallyspaced, the average ligament efficiency shall be not lessthan that given by the following rules, which apply toligaments between tube holes, and not to single openings.This procedure may give lower efficiencies in some casesthan those for symmetrical groups which extend a distancegreater than the inside diameter of the shell as coveredunder PG-52. When this occurs, the efficiencies computedby the rules under PG-52 shall be used.

PG-53.2.1 For a length equal to the inside diameterof the drum for the position that gives the minimum effi-ciency, the efficiency shall be not less than that on whichthe maximum allowable working pressure is based. Whenthe diameter of the drum exceeds 60 in. (1 500 mm), thelength shall be taken as 60 in. (1 500 mm) in applyingthis rule.

PG-53.2.2 For a length equal to the inside radius ofthe drum for the position that gives the minimum efficiency,the efficiency shall be not less than 80% of that on whichthe maximum allowable working pressure is based. Whenthe radius of the drum exceeds 30 in. (750 mm), the lengthshall be taken as 30 in. (750 mm) in applying this rule.

PG-53.3 For holes placed longitudinally along a drumbut that do not come in a straight line, the above rules forcalculating efficiency shall hold except that the equivalentlongitudinal width of a diagonal ligament shall be used.To obtain the equivalent width the longitudinal pitch of thetwo holes having a diagonal ligament shall be multiplied bythe efficiency of the diagonal ligament. The efficiency tobe used for the diagonal ligaments is given in Fig. PG-52.6.

PG-55 SUPPORTS AND ATTACHMENTLUGS

PG-55.1 Lugs or hangers when used to support a boilerof any type shall be properly fitted to the surfaces to whichthey are attached.

PG-55.2 Lugs, hangers, or brackets may be attachedby fusion welding provided the welding meets the require-ments of Part PW, including stress relieving but omitting

41

volumetric examination and provided they are attached byfull penetration welds, combination groove and fillet welds,or by fillet welds along the entire periphery or contactedges. Some acceptable forms of welds for lugs, hangers,or brackets are shown in Fig. PW-16.2. The materials forlugs, hangers, or brackets are not limited to those listed inTables 1A and 1B of Section II, Part D, but shall be ofweldable quality. The allowable load on the fillet weldsshall equal the product of the weld area based on minimumleg dimension, the allowable stress value in tension of thematerial being welded, and the factor 0.55. When usingwelded pipe, the stress values given in Table 1A of SectionII, Part D, may be increased to that of the basic materialby eliminating the stated weld efficiencies.

BOILER EXTERNAL PIPINGAND BOILER PROPER CONNECTIONS

PG-58 OUTLETS AND EXTERNAL PIPINGPG-58.1 General. The rules of this subparagraph apply

to the boiler external piping as defined in the Preamble.

PG-58.2 Boiler External Piping Connections to Boil-ers. All boiler external piping connected to a boiler forany purpose shall be attached to one of the types of jointslisted in PG-59.1.1.1, PG-59.1.1.2, and PG-59.1.1.3.

PG-58.3 Boiler External Piping. The followingdefines the Code Jurisdictional Limits of the boiler externalpiping systems, including general requirements, valves,and inspection. The limits are also shown in Figs. PG-58.3.1, PG-58.3.2, and PG-58.3.3. The materials, design,fabrication, installation, and testing shall be in accordancewith ASME B31.1, Power Piping.

PG-58.3.1 The steam piping connected to the boilerdrum or to the superheater outlet header shall extend upto and including the first stop valve in each connection,except as required by PG-58.3.2. In the case of a singleboiler and prime mover installation, the stop valve requiredherein may be omitted provided the prime mover throttlevalve is equipped with an indicator to show whether thevalve is open or closed and is designed to withstand therequired hydrostatic pressure test of the boiler.

For an isolable or separately fired superheater whichdischarges steam directly to a process stream, the stopvalve required by this paragraph and the safety valve(s)required by PG-68 may be omitted provided the followingconditions are satisfied:

(a) The boiler is a drum-type boiler in a single-boilerinstallation.

(b) The steam discharge passes through the processstream to the atmosphere with no intervening valves.

(c) The system shall be designed so that the processstream through which the steam discharge passes cannot



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

FIG. PG-52.6 DIAGRAM FOR DETERMINING EQUIVALENTLONGITUDINAL EFFICIENCY OF DIAGONAL LIGAMENTS

BETWEEN OPENINGS IN CYLINDRICAL SHELLS

100

90

80

70

60

50

40

30

20

10

0

Eq

uiv

alen

t lo

ng

itu

din

al e

ffic

ien

cy o

f d

iag

on

al li

gam

ent,

%

Angle of diagonal with longitudinal, , deg

sec2 + 1 − secp ′/d

% =0.015 + 0.005 sec2

GENERAL NOTES:(a) The equation in Note (b) below is provided for the user’s option. The use of the equation is

prohibited beyond the range of the abscissa and ordinate shown.(b) Equivalent longitudinal efficiency,

0 10 20 30 40 50 60 70 80 90

20.0

10.0

5.0

4.0

3.0

2.5

2.0

1.8

1.7

1.6

1.5

1.4

1.3

p ′ = diagonal pitchd = diameter of tube holes = p ′ cos

s

d

p ′

Drumaxis

= 1.2p ′d

3 + sec2 θ

θ

θ

θ

θ

θ

θ

42



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

FIG. PG-58.3.1(a) CODE JURISDICTIONAL LIMITS FOR PIPING — DRUM-TYPE BOILERS

Integral

Single installation

Multiple installationCommon header

Drain

Drain

Drain

Drain Common header

Drain

Boiler no. 2

Boiler no. 2

Boiler no. 1

Boiler no. 1

Part PFH

Vent

PG-58.3.6

PG-58.3.1

PG-58.3.7

PG-68.1

PG-68.2

PG-58.3.2

PG-58.3.7

PG-71

PG-58.3.2

Water drum

economizer

Level indicators PG-60

superheater

Inlet header (if used)

Steam drum

Vent

Vent

Vents and instrumentation

Blow-off single and multiple installations

Two or more boilers fed from a common source

Two or more boilers fed from a common source

Regulating valves

Single boilerSingle boiler

Feed

wat

er s

yste

ms

P

G-5

8.3.

3

Control device PG-60

Multiple installation

Main steamPG-58.3.1 Soot blowers PG-68.5

Soot blowers PG-68.5

Surface blowContinuous blowChemical feedDrum sample

Single installation

Administrative Jurisdiction & Technical Responsibility

Boiler Proper — The ASME Boiler and Pressure Vessel Code (ASME BPVC) has totaladministrative jurisdiction and technical responsibility (refer to Section I Preamble)

Boiler External Piping and Joint — The ASME BPVC has total administrative jurisdiction(mandatory certification by Code Symbol stamping, ASME Data Forms, and Authorized Inspection) of Boiler External Piping and Joint. The ASME Section Committee B31.1has been assigned technical responsibilty.

Non-Boiler External Piping and Joint — Not Section I jusidiction (see applicable ASMEB31 Code).

(if used)

Integral

(if used)

43

(10)



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

(10)

FIG

.PG

-58.

3.1(

b)CO

DE

JUR

ISD

ICTI

ONA

LLI

MIT

SFO

RP

IPIN

G—

ISOL

AB

LEE

CON

OMIZ

ER

SLO

CATE

DIN

FEE

DW

ATE

RP

IPIN

GA

ND

ISOL

AB

LESU

PE

RH

EA

TER

SIN

MA

INST

EA

MP

IPIN

G(B

oile

rP

ress

ure

Rel

ief

Val

ves,

Blo

wof

f,an

dM

isce

llane

ous

Pip

ing

for

Boi

ler

Pro

per

Not

Sho

wn

for

Cla

rity

)

Iso

lab

leM

ain

ste

am

refe

r to

Fig

.

PG

-58.

3.1(

a)

Bo

iler

pro

per

[S

ee F

ig.

PG

-58.

3.1

(a)]

Dra

in

P

G-5

8.3.

7

Dra

in

P

G-5

8.3.

7

Inle

t h

ead

er

(if

use

d)

Inte

rven

ing

va

lve

PG

-59.

5.1

Inte

rven

ing

va

lve

PG

-68.

3

Ven

t

Ven

t

Su

per

hea

ter

A

dm

inis

trat

ive

Juri

sdic

tio

n &

Tec

hn

ical

Res

po

nsi

bili

ty

Bo

iler

Pro

per

— T

he

AS

ME

Bo

iler

and

Pre

ssu

re V

esse

l Co

de

(AS

ME

BP

VC

) h

as t

ota

lad

min

istr

ativ

e ju

risd

icti

on

an

d t

ech

nic

al r

esp

on

sib

ility

(re

fer

to S

ecti

on

I P

ream

ble

)

Bo

iler

Ext

ern

al P

ipin

g a

nd

Jo

int

— T

he

AS

ME

BP

VC

has

to

tal a

dm

inis

trat

ive

juri

sdic

tio

n(m

and

ato

ry c

erti

fica

tio

n b

y C

od

e S

ymb

ol s

tam

pin

g, A

SM

E D

ata

Form

s, a

nd

Au

tho

rize

d

Insp

ecti

on

) o

f B

oile

r E

xter

nal

Pip

ing

an

d J

oin

t. T

he

AS

ME

Sec

tio

n C

om

mit

tee

B31

.1h

as b

een

ass

ign

ed t

ech

nic

al r

esp

on

sib

ilty.

No

n-B

oile

r E

xter

nal

Pip

ing

an

d J

oin

t —

No

t S

ecti

on

I ju

sid

icti

on

(se

e ap

plic

able

AS

ME

B31

Co

de)

.

Iso

lab

le

Dra

in

P

G-5

8.3.

7

PG

-67.

2.6

Dra

in

P

G-5

8.3.

7

Ven

t

Ven

t Feed

wat

er

syst

ems

P

G-5

8.3.

3

Eco

no

miz

er

44



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

FIG. PG-58.3.1(c) CODE JURISDICTIONAL LIMITS FOR PIPING — REHEATERS AND NONINTEGRALSEPARATELY FIRED SUPERHEATERS

superheater

Drain PG-58.3.7

Drain PG-58.3.7

Hot reheat PG-59.5.1.1

Cold reheat

Drain PG-58.3.7

Drain PG-58.3.7

Inlet header (if used)

PG-68.3

Vent

Steam out

Steam in

Vent

PG-68.4

PG-68.4

Vent

Vent

Reheater



Boiler External Piping and Joint — The ASME BPVC has total administrative jurisdiction(mandatory certification by Code Symbol stamping, ASME Data Forms, and Authorized Inspection) of Boiler External Piping and Joint. The ASME Section Committee B31.1has been assigned technical responsibilty.


Nonintegral separately fired

45

(10)



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

(10)

2010 SECTION I

FIG. PG-58.3.2 CODE JURISDICTIONAL LIMITS FOR PIPING — AN EXAMPLE OFFORCED-FLOW STEAM GENERATORS WITH NO FIXED STEAM OR WATERLINE

Convection and radiant section

Reheater

Superheater

Economizer

Start-up system may vary to suit boiler manufacturer

Turbine valve or code stop valve PG-58.3.1

Turbine

To equipment

Condenser

Alternates PG-58.3.5

Boiler feed pump



Boiler External Piping and Joint — The ASME BPVC has total administrative jurisdiction(mandatory certification by Code Symbol stamping, ASME Data Forms, and Authorized Inspection) of Boiler External Piping and Joint. The ASME Section Comitee B31.1has been assigned technical responsibilty.


46



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2010 SECTION I

FIG. PG-58.3.3 CODE JURISDICTIONAL LIMITS FOR PIPING — AN EXAMPLE OF STEAM SEPARATOR TYPEFORCED-FLOW STEAM GENERATORS WITH NO FIXED STEAM OR WATERLINE

Boiler feed pump

Alternates PG-58.3.5

(if used) (if used)

(if used)

Water

collector

Recirculation pump

(if used)

Steam

separator

Superheater

Reheater

Turbine

To equipment

Economizer

Convection

and radiant

section

Start-up system

may vary to suit

boiler manufacturer

Turbine valve or

Code stop valve

PG-58.3.1

ADMINISTRATIVE JURISDICTION AND TECHNICAL RESPONSIBILITY

Boiler Proper – The ASME Boiler and Pressure Vessel Code (ASME BPVC) has total

administrative jurisdiction and technical responsibility (refer to Section I Preamble).

Boiler External Piping and Joint – The ASME BPVC has total administrative jurisdiction

(mandatory certification by Code Symbol stamping, ASME Data Forms, and Authorized

Inspection) of Boiler External Piping and Joint. The ASME Section Committee B31.1

has been assigned technical responsibility.

Non-Boiler External Piping and Joint – Not Section I jurisdiction (see applicable ASME

B31 Code).

47

(10)



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2010 SECTION I

be obstructed in such a way as to cause the pressure inthe superheater to exceed that permitted by PG-67.2, withmaximum steam flow from the boiler to the superheater.Flow and pressure calculations demonstrating that thesuperheater will not be overpressurized under any steamflow conditions shall be documented and made availableto the Inspector. These calculations shall be certified by aProfessional Engineer experienced in the mechanicaldesign of power plants.

(d) There is no valve on the discharge side of the super-heater.

(e) Section I jurisdiction shall include the pressure partsbetween the superheater inlet and the outlet at

(1) the first circumferential joint for welding end con-nections

(2) the face of the first flange in bolted flange connec-tions or

(3) the first threaded joint in that type of connection

PG-58.3.2 When two or more boilers are connectedto a common steam header, or when a single boiler isconnected to a header having another steam source (e.g.,a turbine extraction line), the connection from each boilerhaving a manhole opening shall be fitted with two stopvalves having an ample free-blow drain between them. Theboiler external piping includes all piping from the boilerproper up to and including the second stop valve and thefree-blow drain valve.

PG-58.3.3 The feedwater piping for all boilers,except high-temperature water boilers and forced-flowsteam generators complying with PG-58.3.5, shall extendthrough the required stop valve and up to and includingthe check valve except as required by PG-58.3.4. On asingle boiler-turbine unit installation the boiler feed shutoffvalve may be located upstream from the boiler feed checkvalve.

If a feedwater heater or heaters meeting the requirementsof Part PFH are installed between the required stop valveand the boiler, and are fitted with isolation and bypassvalves, provisions must be made to prevent the feedwaterpressure from exceeding the maximum allowable workingpressure of the piping or feedwater heater, whichever isless. Control and interlock systems are permitted in orderto prevent overpressure.

PG-58.3.4 When two or more boilers are fed froma common source, the piping shall be up to and includinga globe or regulating valve located between the check valverequired in PG-58.3.3 and the source of supply. If theregulating valve is equipped with an isolation valve and abypass valve, the piping shall be up to and including boththe isolation valve downstream from the regulating valveand the shutoff valve in the bypass.

PG-58.3.5 The feedwater piping for a forced-flowsteam generator with no fixed steam and waterline may

48

terminate up to and including the stop valve near the boilerand omitting the check valve near the boiler, provided thata check valve having a pressure rating no less than theboiler inlet design pressure is installed at the discharge ofthe boiler feed pump or elsewhere in the feedline betweenthe feed pump and the feed stop valve. If the feedwaterheater(s) is fitted with isolation and bypass valves, theapplicable requirements of PG-58.3.3 must be met.

PG-58.3.6 The blowoff piping for all boilers, exceptforced-flow steam generators with no fixed steam andwaterline, high-temperature water boilers, and those usedfor traction and/or portable purposes, when the maximumallowable working pressure exceeds 100 psi (700 kPa)shall extend through and including the second valve. Theblowoff piping for all traction and/or portable boilers andfor forced circulation and electric boilers having a normalwater content not exceeding 100 gal (380 L) are requiredto extend through only one valve.

PG-58.3.7 The miscellaneous piping shall includethe piping for such items as drains, vents, surface-blow-off, steam and water piping for water columns, gage glassesand pressure gages. When a drain is not intended for blow-off purposes (when the boiler is under pressure) a singlevalve is acceptable, otherwise two valves in series arerequired except as permitted by PG-58.3.6.

PG-58.3.8 Boiler external piping for single high-temperature water boilers shall extend from the connectionsto the boiler up to and including the first stop valve andshall be classified as miscellaneous piping.

When multiple high-temperature water boilers are con-nected to common supply and return piping, and containopenings of a size that permit entry into the vessel, thesupply and return piping systems shall meet the require-ments of PG-58.3.2, including the requirement for a free-blown drain.

PG-58.3.9 Welded piping in PG-58.3.1, PG-58.3.2,PG-58.3.3, PG-58.3.4, PG-58.3.5, PG-58.3.6, PG-58.3.7,and PG-58.3.8 is also subject to the requirements of PG-104for proper Code certification.

PG-59 APPLICATION REQUIREMENTS FORTHE BOILER PROPER

PG-59.1 Common to Steam, Feedwater, Blowoff,and Drain Systems

PG-59.1.1 Outlets of a boiler to which piping is tobe attached for any purpose, and which piping comes withinthe Code requirements, shall meet the requirements ofPG-39 and shall be

PG-59.1.1.1 A tapped opening.

PG-59.1.1.2 Bolted flanged joints including thoseof the Van Stone type.



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2010 SECTION I

FIG. PG-59.1 TYPICAL BOILER BUSHINGS

PG-59.1.1.3 Welding ends of the butt or socketwelding type.

PG-59.1.1.4 Piping within the boiler proper maybe expanded into grooved holes, seal welded if desired.Blowoff piping of firetube boilers shall be attached bythreading into a tapped opening with a threaded fitting orvalve at the other end if exposed to products of combustion,or by PG-59.1.1.1 or PG-59.1.1.2 if not so exposed (seePFT-49).

PG-59.1.2 Steam Mains. Provisions shall be madefor the expansion and contraction of steam mains connectedto boilers, by providing substantial anchorage at suitablepoints, so that there shall be no undue strain transmittedto the boiler. Steam reservoirs shall be used on steammains when heavy pulsations of the steam currents causevibration of the boiler shell plates.

PG-59.1.3 Figure PG-59.1 illustrates a typical formof connection for use on boiler shells for passing throughpiping such as feed, surface blowoff connections, etc., andwhich permits the pipes’ being threaded in solid from bothsides in addition to the reinforcing of the opening of theshell. The pipes shall be attached as provided in PG-59.1.1.

In these and other types of boilers where both internaland external pipes making a continuous passage areemployed, the boiler bushing or its equivalent shall be used.

PG-59.2 Requirements for Feedwater Connections.The feedwater shall be introduced into a boiler in such amanner that the water will not be discharged directlyagainst surfaces exposed to gases of high temperature orto direct radiation from the fire. For pressures of 400 psi

49

(3 MPa) or over, the feedwater inlet through the drum shallbe fitted with shields, sleeves, or other suitable means toreduce the effects of temperature differentials in the shellor head. Feedwater, other than condensate returns as pro-vided for in PG-59.3.6, shall not be introduced throughthe blowoff.

PG-59.3 Requirements for Blowoffs

PG-59.3.1 A blowoff as required herein is definedas a pipe connection provided with valves located in theexternal piping through which the water in the boiler maybe blown out under pressure, excepting drains such as areused on water columns, gage glasses, or piping to feedwaterregulators, etc., used for the purpose of determining theoperating condition of such equipment. Piping connectionsused primarily for continuous operation, such as deconcen-trators on continuous blowdown systems, are not classedas blowoffs but the pipe connections and all fittings up toand including the first shutoff valve shall be equal at leastto the pressure requirements for the lowest set pressure ofany pressure relief valve on the boiler drum and with thecorresponding saturated-steam temperature.

PG-59.3.2 A surface blowoff connection shall notexceed NPS 21⁄2 (DN 65), and the internal pipe and theterminal connection for the external pipe, when used, shallform a continuous passage, but with clearance betweentheir ends and arranged so that the removal of either willnot disturb the other. A properly designed steel bushing,similar to or the equivalent of those shown in Fig. PG-59.1, or a flanged connection shall be used.



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2010 SECTION I

PG-59.3.3 Each boiler except forced-flow steamgenerators with no fixed steam and waterline and high-temperature water boilers shall have a bottom blowoffoutlet in direct connection with the lowest water spacepracticable for external piping conforming to PG-58.3.6.

PG-59.3.4 All waterwalls and water screens that donot drain back into the boiler, and all integral economizers,shall be equipped with outlet connections for a blowoff ordrain line and conform to the requirements of PG-58.3.6or PG-58.3.7.

PG-59.3.5 Except as permitted for miniature boilersin Part PMB and for boilers with 100 ft2 (9.3 m2) of heatingsurface or less, the minimum size of blowoff connectionsshall be NPS 1 (DN 25) and the maximum size shall beNPS 21⁄2 (DN 65). Boilers with 100 ft2 (9.3 m2) or less butmore than 20 ft2 (1.9 m2) of heating surface may have aminimum size blowoff connection of NPS 3⁄4 (DN 20).Boilers with 20 ft2 (1.9 m2) or less of heating surfacemay have a minimum size blowoff connection of NPS 1⁄2(DN 15).

PG-59.3.6 Condensate return connections of thesame size or larger than the size herein specified may beused, and the blowoff may be connected to them. In suchcase the blowoff shall be so located that the connectionmay be completely drained.

PG-59.3.7 A bottom blowoff pipe when exposed todirect furnace heat shall be protected by firebrick or otherheat resisting material that is so arranged that the pipe maybe inspected.

PG-59.3.8 An opening in the boiler setting for ablowoff pipe shall be arranged to provide free expansionand contraction.

PG-59.4 Requirements for Drains

PG-59.4.1 Ample drain connections shall be pro-vided where required to permit complete drainage of allpiping, superheaters, waterwalls, water screens, economiz-ers, and all other boiler components in which water maycollect. Piping shall conform to the requirements ofPG-58.3.6 or PG-58.3.7.

PG-59.4.1.1 Each superheater shall be equippedwith at least one drain connection so located as to mosteffectively provide for the proper operation of the appa-ratus.

PG-59.4.1.2 Each high-temperature water boilershall have a bottom drain connection of at least NPS 1(DN 25) in direct connection with the lowest water spacepractical for external piping conforming to PG-58.3.8.

PG-59.5 Requirements for Valves and Fittings. Thefollowing requirements apply to the use of valves andfittings in the boiler proper.

50

PG-59.5.1 Steam Stop ValvesPG-59.5.1.1 If a shutoff valve is used between

the boiler and its superheater, the pressure relief valvecapacity on the boiler shall comply with the requirementsof PG-67.2 and PG-70, except as provided for inPG-59.5.1.2, no credit being taken for the pressure reliefvalve on the superheater, and the superheater must beequipped with pressure relief valve capacity as requiredby PG-68. A stop valve is not required at the inlet or theoutlet of a reheater or separately fired superheater.

PG-59.5.1.2 When stop valves are installed in thewater-steam flow path between any two sections of aforced-flow steam generator with no fixed steam and water-line, the pressure relief valves shall satisfy the requirementsof PG-67.4.4.

DESIGN AND APPLICATION

PG-60 REQUIREMENTS FORMISCELLANEOUS PIPE,VALVES, AND FITTINGS

Piping referred to in this paragraph shall be designed inaccordance with the applicable requirements of ASMEB31.1.

PG-60.1 Water Level Indicators. All boilers havinga fixed water level (steam and water interface) shall haveat least one gage glass (a transparent device that permitsvisual determination of the water level). Gage glass designsthat utilize transverse structural members (cross webbing)as a means to strengthen the body of the gage, which arenot continuous over the entire vertical length of the gageglass, are not permitted.20 Boilers not having a fixed waterlevel, such as forced-flow steam generators and high-tem-perature water boilers of the forced circulation type, arenot required to have a gage glass. The lowest visible waterlevel in a gage glass shall be at least 2 in. (50 mm) abovethe lowest permissible water level, as determined by theboiler Manufacturer. Electrode-type electric boilers arerequired to have only one gage glass, regardless of MAWP.

Gage glass assemblies having multiple sections, whetherof tubular or other construction, shall be designed in sucha manner that will ensure a minimum of 1 in. (25 mm)overlap of all adjoining sections in which the water levelmay be visible, except that ported gages or reflex gagesthat use refraction of light to aid ready determination ofthe liquid level, may omit the requirement for overlappingsections.

20 Transverse or cross-web structural strengthening members will causeareas along the length of the gage glass where the liquid level cannot bereadily determined because of the masking shadows caused by the pres-ence of the transverse members. Reflex-type designs that utilize solidmembers behind the glass that are continuous over the vertical length ofthe glass, and front lit by either ambient or projected sources as applicable,are not prohibited.



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2010 SECTION I

PG-60.1.1 Boilers having a maximum allowableworking pressure exceeding 400 psi (3 MPa) shall havetwo gage glasses. Instead of one of the two required gageglasses, two independent remote water level indicators (twodiscrete systems that continuously measure, transmit, anddisplay water level) may be provided.

PG-60.1.1.1 When the water level in at least onegage glass is not readily visible to the operator in the areawhere control actions are initiated, either a fiber optic cable(with no electrical modification of the optical signal) ormirrors shall be provided to transfer the optical imageof the water level to the control area. Alternatively, anycombination of two of the following shall be provided:

(a) an independent remote water level indicator(b) an independent continuous transmission and display

of an image of the water level in a gage glass

PG-60.1.1.2 When two independent remote waterlevel indicators are in reliable operation (continuously indi-cating water level), the one required gage glass may be shutoff, but shall be maintained in the serviceable condition.

PG-60.1.1.3 The display of a remote water levelindicator shall have a clearly marked minimum water levelreference at least 2 in. (50 mm) above the lowest permissi-ble water level, as determined by the Manufacturer.

PG-60.1.1.4 Independent remote level indicatorsthat contain sensing devices that include a magneticallycoupled float inside a nonmagnetic cylindrical pressurechamber to utilize through-the-wall sensing of float posi-tion shall be restricted to the requirements of PG-12.2.21

The design and construction of such devices shall includeprovisions for ease of cleaning and maintenance. Attach-ment of any control devices for use other than indicatingwater level is prohibited.

PG-60.1.6 Each gage glass or austenitic stainlesssteel or nickel-based alloy water level-sensing device shallbe fitted with a drain cock or valve having an unrestricteddrain opening of not less than 1⁄4 in. (6 mm) diameter tofacilitate cleaning. When the boiler MAWP exceeds 100 psi(700 kPa), the gage glass shall be furnished with a connec-tion to install a valved drain to a point of safe discharge.

Each gage glass or austenitic stainless steel or nickel-based alloy water level-sensing device shall be equippedwith a top and a bottom shutoff valve of such through-flow construction as to prevent stoppage by deposits ofsediments. See PG-60.3.7(a) through (e) for examples ofacceptance valve construction. If the bottom valve is morethan 7 ft (2 m) above the floor or platform from which itis operated, the operating mechanism shall indicate by itsposition whether the valve is open or closed. The pressure–

21 Such float-type devices are calibrated for a specific range of pressuresand temperatures, and restrictions specified by the remote indicator manu-facturer shall be satisfied.

51

temperature rating of valves, fittings, and piping shall beat least equal to the boiler MAWP and the correspondingsaturated-steam temperature.

Straight-run globe valves shall not be used on such con-nections. Automatic shutoff valves as referenced here, arevalves intended to automatically restrict flow in the eventof a gage glass failure without human intervention, andshall conform to the requirements given in A-18.

PG-60.1.7 As used in this section, “automated isola-tion valve” shall be taken to mean a device that is actuatedelectrically, pneumatically, or hydraulically to temporarilyisolate a gage glass. It is required that the closing andopening sequences of such a device be manually initiatedby the operator.

Automated isolation valves may be used, provided(a) all piping and fittings between the sight glass and

the boiler, or sight glass and water column, are designedfor internal inspection and cleaning, or are designed toallow passage internally of a rotary cleaning tool. Thevalves shall be of such through-flow construction as toprevent stoppage by deposits of sediment.

(b) the valves are equipped with opened and closedindicators that can readily be seen from the valve operatingfloor or platform. The design of the valves shall be suchas to prevent indicating a false opened or closed condition.

(c) a means of manually opening and closing the valvesfrom the valve operating floor or platform is provided.

(d) automated isolation valves are designed to fail-safein the as-is condition.

PG-60.2 Water Columns

PG-60.2.1 A water column shall be so mounted thatit will be correctly positioned, relative to the normal waterlevel under operating conditions.

PG-60.2.3 Each water column shall be furnishedwith a connection of at least NPS 3⁄4 (DN 20) to install avalved drain to a safe point of discharge.

PG-60.2.4 The design and material of a water col-umn shall comply with the requirements of PG-8.2, PG-8.3,and PG-42.

PG-60.3 Connections

PG-60.3.1 Gage glasses that are required by PG-60.1shall be connected directly to the shell or drum of theboiler or to an intervening water column. When two gageglasses are required, both may be connected to a singlewater column.

PG-60.3.2 The lower edge of the steam connectionbetween a water column, gage glass, or austenitic stainlesssteel or nickel-based alloy water level-sensing device inthe boiler shall not be below the highest visible water levelin the gage glass. There shall be no sag or offset in thepiping that will permit the accumulation of water.



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2010 SECTION I

PG-60.3.3 The upper edge of the water connectionbetween a water column, gage glass, or austenitic stainlesssteel or nickel-based alloy water level-sensing device andthe boiler shall not be above the lowest visible water levelin the gage glass. No part of this pipe connection shall beabove the point of connection at the water column.

PG-60.3.4 Connections from the boiler to the watercolumn shall be at least NPS 1 (DN 25). Connections forgage glasses connected directly to the boiler or to anintervening water column shall be at least NPS 1⁄2 (DN 15).Connections from the boiler to the remote level indicatorshall be at least NPS 3⁄4 (DN 20) to and including the isola-tion valve and from there to the remote level indicator atleast 1⁄2 in. (13 mm) O.D. tubing.

PG-60.3.5 When the boiler MAWP exceeds 400 psi(3 MPa), lower connections to drums for water columnsand remote level indicators shall be provided with shields,sleeves, or other suitable means to reduce the effect oftemperature differentials in the shells or heads.

PG-60.3.6 The steam and water connections to awater column, gage glass, or austenitic stainless steel ornickel-based alloy water level-sensing device shall bereadily accessible for internal inspection and cleaning.Some acceptable methods of meeting this requirement areby providing a cross or fitting with a back outlet at eachright-angle turn to permit inspection and cleaning in bothdirections, or by using pipe bends or fittings of a type thatdoes not leave an internal shoulder or pocket in the pipeconnection and with a radius of curvature that will permitthe passage of a rotary cleaner. Screwed plug closuresusing threaded connections as allowed by PG-39.5.3 areacceptable means of access for this inspection and cleaning.When the boiler MAWP exceeds 400 psig (3 MPa), socket-welded plugs may be used for this purpose in lieu ofscrewed plugs. If the water connection to the water columnhas a rising bend or pocket that cannot be drained by meansof the water-column drain, an additional drain shall beplaced on this connection so that it may be blown off toclear any sediment from the pipe.

PG-60.3.7 Shutoff valves, including automatedvalves as described in PG-60.1.7, if provided in the pipeconnections between a boiler and a water column orbetween a boiler and the shutoff valves required for thegage glass, or austenitic stainless steel or nickel-based alloywater level-sensing device (PG-60.1.6), shall be of suchthrough-flow construction as to prevent stoppage by depos-its of sediment and shall indicate whether they are in openor closed position of the operating mechanism.

Some examples of acceptable valves are(a) outside-screw-and-yoke type gate valve(b) lever-lifting-type gate valve with permanently fas-

tened lever

52

FIG. PG-60.3.7 Y-TYPE GLOBE VALVE

D 1/4 D min.

(c) stopcock with the plug held in place by a guardor gland

(d) ball valve(e) Y-type globe valve with rising stem so constructed

that the lowest edge of the seat is at least 25% of the insidediameter below the centerline of the valve as shown inFig. PG-60.3.7.

Such valves shall be locked or sealed open except underthe following additional conditions:

(1) The boiler MAWP shall not exceed 250 psig(1.7 MPa).

(2) The boiler shall not be hand fired or fired withsolid fuel not in suspension.

(3) Interlocks between the valve and the burner con-trol system shall stop fuel supply and prevent firing when-ever the valve between the drum and the water column isnot in the fully open position.

(4) The minimum valve size shall be NPS 1 (DN 25).

PG-60.3.7.1 Automated isolation valves (asdescribed in PG-60.1.7) need not be locked or sealed openas noted above.

PG-60.3.8 Except for control devices such as damperregulators and feedwater regulators, drains, steam pressuregages, or apparatus of such form as does not permit theescape of an appreciable amount of steam or water there-from, no outlet connections shall be placed on the pipingconnecting a water column or gage glass to a boiler. Nooutlet connections shall be placed on the piping connectinga remote level indicator to the boiler or to a water columnfor any function other than water level indication.

PG-60.3.9 An acceptable arrangement is shown inFig. PG-60.3.9.

PG-60.4 Gage Cocks. Not required.

PG-60.5 Water Fronts. Each boiler fitted with a waterjacketed boiler-furnace mouth protector, or similar appli-ance having valves on the pipes connecting them to the



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2010 SECTION I

FIG. PG-60.3.9 TYPICAL ARRANGEMENT OF STEAMAND WATER CONNECTIONS FOR A WATER

COLUMN

Steam

Steam

WaterWater

A — not lower than B

C — not higher than D

C C

A

AB

D

B

D

Gla

ss

boiler shall have these valves locked or sealed open. Suchvalves, when used, shall be of the straightway type.

PG-60.6 Pressure GagesPG-60.6.1 Each boiler shall have a pressure gage so

located that it is easily readable. The pressure gage shallbe installed so that it shall at all times indicate the pressurein the boiler. Each steam boiler shall have the pressuregage connected to the steam space or to the water columnor its steam connection. A valve or cock shall be placedin the gage connection adjacent to the gage. An additionalvalve or cock may be located near the boiler providing itis locked or sealed in the open position. No other shutoffvalves shall be located between the gage and the boiler.The pipe connection shall be of ample size and arrangedso that it may be cleared by blowing out. For a steamboiler the gage or connection shall contain a syphon orequivalent device that will develop and maintain a waterseal that will prevent steam from entering the gage tube.Pressure gage connections shall be suitable for the maxi-mum allowable working pressure and temperature, but ifthe temperature exceeds 406°F (208°C), brass or copperpipe or tubing shall not be used. The connections to theboiler, except the syphon, if used, shall not be less thanNPS 1⁄4 (DN 8) but where steel or wrought iron pipe ortubing is used, they shall not be less than 1⁄2 in. (13 mm)inside diameter. The minimum size of a syphon, if used,shall be 1⁄4 in. (6 mm) inside diameter. The dial of thepressure gage shall be graduated to approximately doublethe pressure at which the safety valve is set, but in no caseto less than 11⁄2 times this pressure.

53

PG-60.6.2 Each forced-flow steam generator withno fixed steam and waterline shall be equipped with pres-sure gages or other pressure measuring devices located asspecified in PG-60.6.2.1 through PG-60.6.2.3.

PG-60.6.2.1 at the boiler or superheater outlet(following the last section, which involves absorption ofheat)

PG-60.6.2.2 at the boiler or economizer inlet (pre-ceding any section that involves absorption of heat), and

PG-60.6.2.3 upstream of any shutoff valve thatmay be used between any two sections of the heat absorbingsurface

PG-60.6.3 Each boiler shall be provided with a valveconnection at least NPS 1⁄4 (DN 8) for the exclusive purposeof attaching a test gage when the boiler is in service,so that the accuracy of the boiler pressure gage can beascertained.

PG-60.6.4 Each high-temperature water boiler shallhave a temperature gage so located and connected that itshall be easily readable. The temperature gage shall beinstalled so that it at all times indicates the temperature indegrees Fahrenheit (Celsius) of the water in the boiler, ator near the outlet connection.

PG-61 FEEDWATER SUPPLYPG-61.1 Except as provided for in PG-61.2 and

PG-61.4, boilers having more than 500 ft2 (47 m2) of water-heating surface shall have at least two means of feedingwater. Except as provided for in PG-61.3, PG-61.4, andPG-61.5, each source of feeding shall be capable of supply-ing water to the boiler at a pressure of 3% higher than thehighest setting of any pressure relief valve on the boilerproper. For boilers that are fired with solid fuel not insuspension, and for boilers whose setting or heat sourcecan continue to supply sufficient heat to cause damage tothe boiler if the feed supply is interrupted, one such meansof feeding shall not be susceptible to the same interruptionas the other, and each shall provide sufficient water toprevent damage to the boiler.

PG-61.2 Except as provided for in PG-61.1, a boilerfired by gaseous, liquid, or solid fuel in suspension, orheated by combustion turbine engine exhaust, may beequipped with a single means of feeding water, providedmeans are furnished for the shutting off of its heat inputprior to the water level reaching the lowest permissiblelevel established by PG-60.

PG-61.3 For boilers having a water-heating surface ofmore than 100 ft2 (9.3 m2), the feed water connection tothe boiler shall be not less than NPS 3⁄4 (DN 20).

For boilers having a water-heating surface of 100 ft2

(9.3 m2) or less, the feed water connection to the boilershall be not less than NPS 1⁄2 (DN 15).



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(10)

2010 SECTION I

Boilers with 20 ft2 (1.9 m2) or less of water heatingsurface may have the feed water delivered through theblowoff opening.

PG-61.4 High-temperature water boilers shall be pro-vided with means of adding water to the boiler or systemwhile under pressure.

PG-61.5 A forced-flow steam generator with no fixedsteam and waterline shall be provided with a source offeeding capable of supplying water to the boiler at a pres-sure not less than the expected maximum sustained pres-sure at the boiler inlet, as determined by the boilerManufacturer, corresponding to operation at maximumdesigned steaming capacity with maximum allowableworking pressure at the superheater outlet.

OVERPRESSURE PROTECTIONREQUIREMENTS

PG-67 BOILER

PG-67.1 Each boiler shall have at least one pressurerelief valve and if it has more than 500 ft2 (47 m2) of baretube water-heating surface, or if an electric boiler has apower input more than 1,100 kW, it shall have two ormore pressure relief valves. For a boiler with combinedbare tube and extended water-heating surface exceeding500 ft2 (47 m2), two or more pressure relief valves arerequired only if the design steam generating capacity ofthe boiler exceeds 4,000 lb /hr (1 800 kg/hr). Organic fluidvaporizer generators require special consideration as givenin Part PVG.

PG-67.2 The pressure relief valve capacity for eachboiler (except as noted in PG-67.4) shall be such that thepressure relief valve, or valves will discharge all the steamthat can be generated by the boiler without allowing thepressure to rise more than 6% above the highest pressureat which any valve is set and in no case to more than 6%above the maximum allowable working pressure.

PG-67.2.1 The minimum required relieving capacityof the pressure relief valves for all types of boilers shallbe not less than the maximum designed steaming capacityat the MAWP of the boiler, as determined by the Manufac-turer and shall be based on the capacity of all the fuelburning equipment as limited by other boiler functions.

PG-67.2.2 The minimum required relieving capacityfor a waste heat boiler shall be determined by the Manufac-turer. When auxiliary firing is to be used in combinationwith waste heat recovery, the maximum output as deter-mined by the boiler Manufacturer shall include the effectof such firing in the total required capacity. When auxiliary

54

firing is to be used in place of waste heat recovery, theminimum required relieving capacity shall be based onauxiliary firing or waste heat recovery, whichever is higher.

PG-67.2.3 The minimum required relieving capacityfor electric boilers shall be in accordance with PEB-15.

PG-67.2.4 The minimum required relieving capacityin lb /hr (kg/hr) for a high-temperature water boiler shallbe determined by dividing the maximum output in Btu /hr(W) at the boiler nozzle, produced by the highest heatingvalue fuel for which the boiler is designed, by 1,000 (646).

PG-67.2.5 The minimum required relieving capacityfor organic fluid vaporizers shall be in accordance withPVG-12. The minimum required relieving capacity forminiature boilers shall be in accordance with PMB-15.

PG-67.2.6 Any economizer that may be shut offfrom the boiler, thereby permitting the economizer tobecome a fired pressure vessel, shall have one or morepressure relief valves with a total discharge capacity, inlb /hr (kg/hr), calculated from the maximum expected heatabsorption in Btu/hr (W), as determined by the Manufac-turer, divided by 1,000 (646). This absorption shall bestated in the stamping (PG-106.4). For overpressure condi-tions where the fluid relieved is water, the discharge capac-ity of the pressure relief valve, or valves shall be sufficientto prevent the pressure from exceeding the limits ofPG-67.2.

PG-67.2.7 The steam generated when all pressurerelief valves are relieving at full lift on a boiler that has asteam-generating surface located downstream in the gasstream of a superheater and/or reheater surface may exceedthe maximum designed steaming capacity at the MAWPof the boiler. The Manufacturer shall address this by oneof the following methods:

PG-67.2.7.1 The minimum required relievingcapacity of the pressure relief valves shall not be less thanthe steam that may be generated with all pressure reliefvalves relieving at full lift. For boilers that use auxiliaryfiring in combination with the primary heat source, theManufacturer shall include the effect of such firing in thetotal required capacity.

PG-67.2.7.2 The minimum required relievingcapacity of the pressure relief valves shall not be less thanthe maximum designed steaming capacity at the MAWPof the boiler, and the boiler shall be provided with controlsresponsive to steam pressure, which include not less thanthe following:

(a) a control that reduces that total heat input to theboiler such that the steam generated does not exceed themaximum designed steaming capacity at the MAWP ofthe boiler

(b) a control that trips the heat input to the boiler if thepressure reaches 106% of the MAWP of the boiler

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PG-67.3 One or more pressure relief valves on theboiler proper shall be set at or below the maximum allow-able working pressure (except as noted in PG-67.4). Ifadditional valves are used the highest pressure setting shallnot exceed the maximum allowable working pressure bymore than 3%. The complete range of pressure settings ofall the saturated-steam pressure relief valves on a boilershall not exceed 10% of the highest pressure to which anyvalve is set. Pressure setting of pressure relief valves onhigh-temperature water boilers22 may exceed this 10%range. Economizer pressure relief devices required by PG-67.2.6 shall be set as above using the MAWP of the econo-mizer.

PG-67.4 For a forced-flow steam generator with nofixed steam and waterline (Fig. PG-67.4), equipped withautomatic controls and protective interlocks responsive tosteam pressure, pressure relief valves may be provided inaccordance with the above paragraphs or the followingprotection against overpressure shall be provided:

PG-67.4.1 One or more power-actuated pressurerelieving valves23 shall be provided in direct communica-tion with the boiler when the boiler is under pressure andshall receive a control impulse to open when the maximumallowable working pressure at the superheater outlet, asshown in the master stamping (PG-106.3), is exceeded. Thetotal combined relieving capacity of the power-actuatedrelieving valves shall be not less than 10% of the maximumdesign steaming capacity of the boiler under any operatingcondition as determined by the Manufacturer. The valveor valves shall be located in the pressure part system wherethey will relieve the overpressure.

An isolating stop valve of the outside-screw-and-yokeor ball type may be installed between the power-actuatedpressure relieving valve and the boiler to permit repairsprovided an alternate power-actuated pressure relievingvalve of the same capacity is so installed as to be in directcommunication with the boiler in accordance with therequirements of this paragraph.

The isolating stop valve port area shall at least equalthe area of the inlet of the power-actuated pressure relievingvalve. If the isolating stop valve is of the ball type, the

22 Pressure relief valves in hot water service are more susceptible todamage and subsequent leakage, than pressure relief valves relievingsteam. It is recommended that the maximum allowable working pressureof the boiler and the pressure relief valve setting for high-temperaturewater boilers be selected substantially higher than the desired operatingpressure so as to minimize the times the pressure relief valve must lift.

23 The power-actuated pressure relieving valve is one whose movementsto open or close are fully controlled by a source of power (electricity,air, steam, or hydraulic). The valve may discharge to atmosphere or toa container at lower pressure. The discharge capacity may be affectedby the downstream conditions, and such effects shall be taken into account.If the power-actuated pressure relieving valves are also positioned inresponse to other control signals, the control impulse to prevent overpres-sure shall be responsive only to pressure and shall override any othercontrol function.

55

valve shall include a means to clearly identify whether thevalve is in the open or closed position. If the isolating stopvalve is power actuated (air, motor, hydraulic, etc.), amanual override mechanism shall be provided.

Power-actuated pressure relieving valves discharging tointermediate pressure and incorporated into bypass and/orstartup circuits by the boiler Manufacturer need not becapacity certified. Instead, they shall be marked by thevalve manufacturer with a capacity rating at a set of speci-fied inlet pressure and temperature conditions. Power-actu-ated pressure relieving valves discharging directly toatmosphere shall be capacity certified. This capacity certi-fication shall be conducted in accordance with the provi-sions of PG-69.3. The valves shall be marked in accordancewith the provisions of PG-69.4.

PG-67.4.2 Pressure relief valves shall be provided,having a total combined relieving capacity, including thatof the power-actuated pressure relieving capacity installedunder PG-67.4.1, of not less than 100% of the maximumdesigned steaming capacity of the boiler, as determinedby the Manufacturer, except the alternate provisions ofPG-67.4.3 are satisfied. In this total, no credit in excess of30% of the total required relieving capacity shall beallowed for the power-actuated pressure relieving valvesactually installed. Any or all of the pressure relief valvesmay be set above the maximum allowable working pressureof the parts to which they are connected, but the set pres-sures shall be such that when all of these valves (togetherwith the power-actuated pressure relieving valves) are inoperation the pressure will not rise more than 20% abovethe maximum allowable working pressure of any part ofthe boiler, except for the steam piping between the boilerand the prime mover.

PG-67.4.3 The total installed capacity of pressurerelief valves may be less than the requirements ofPG-67.4.2 provided all of the following conditions are met.

PG-67.4.3.1 The boiler shall be of no less steam-ing capacity than 1,000,000 lb /hr (450 000 kg/hr) andinstalled in a unit system for power generation (i.e., a singleboiler supplying a single turbine-generator unit).

PG-67.4.3.2 The boiler shall be provided withautomatic devices, responsive to variations in steam pres-sure, which include not less than all the following:

PG-67.4.3.2.1 A control capable of maintainingsteam pressure at the desired operating level and of modu-lating firing rates and feedwater flow in proportion to avariable steam output.

PG-67.4.3.2.2 A control that overrides PG-67.4.3.2.1 by reducing the fuel rate and feedwater flowwhen the steam pressure exceeds the maximum allowableworking pressure as shown in the master stamping(PG-106.3) by 10%, and



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2010 SECTION I

FIG. PG-67.4 REQUIREMENTS FOR OVERPRESSURE PROTECTION FORCED-FLOW STEAM GENERATOR

(2)(3)(5)(B)

(4)(1)

Water walls

Superheater Superheater Turbine

Throttle inlet

Economizer

(A) (C)Check valve

Boiler feed pump

Steam-water flow direction

17%

3%

Maximum set pressure pressure relief valves (PG-67.4.2)

Maximum overpressure (PG-67.4.2 and PG-67.4.3)

Pressure, psi (MPa)

Actual design pressure

Minimum design pressure

Operating pressure

Opening pressure power-actuated valves

Master stamping pressure

Pressure(A) = master stamping (PG-106.3)(B) = component design at inlet to stop valve (5) (PG-67.4.4.1)(C) = turbine throttle inlet (ASME B31.1, para. 122.1.2, A.4)

Pressure Relief and Power-Actuated Valves(1) = power actuated (PG-67.4.1)(2), (3), and (4) = pressure relief valve (PG-67.4.2)(5) = superheater stop (PG-67.4.4)

Pressure Relief Valve Flow Capacity (minimum, based on rated capacity of boiler)(1) = 10% – 30% (PG-67.4.1)(2) = minimum of one valve (PG-68.1)(2) + (3) when downstream to stop valve (5) = that required for independently fired superheaters (PG-68.3)(2) + (3) + (4) = 100% – (1) (PG-67.4.2)

Pressure Relief Valve Opening Pressure (maximum)(1) = (A), and (B) when there is stop valve (5) (PG-67.4.1)(2), (3), and (4) = (A) + 17% (PG-67.4.2)(5) = (A) (PG-67.4.1)

Alternate Requirements for Pressure Relief Valves

Pressure Relief Valve Flow Capacity (minimum, based on rated capacity of boiler)(1) = 10% – 30% (PG-67.4.1)(2) = one valve minimum (PG-68.1)(2) + (3) when downstream to stop valve (5) = that required for independently fired superheaters (PG-68.3)(4) = 10% total with minimum of two valves when there is a stop valve (5) (PG-67.5.3.3)(2) + (4) = 10% with minimum of two valves when there is no stop valve (5) (PG-67.4.3.3)

Pressure Relief Valve Opening Pressure (maximum)(1) = (A), and (B) when there is stop valve (5) (PG-67.4.1)(2), (3), and (4) = (A) + 20% (PG-67.4.3.3)(5) = (A) (PG-67.4.1)

Automatic Pressure Controls (PG-67.4.3)(a) at (C) for normal operation under load (PG-67.4.3.2.1)(b) at (A) + 10% to overide control (a) (PG-67.4.3.2.2)(c) at (A) + 20% to shut off flow of fuel and feedwater (PG-67.4.3.2.3)(d) pressure relief valves at (4) to shut off flow of fuel and feedwater by “fail-safe” power circuit (PG-67.4.3.4)

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PG-67.4.3.2.3 A direct-acting overpressure-trip-actuating mechanism, using an independent pressuresensing device, that will stop the flow of fuel and feedwaterto the boiler, at a pressure higher than the set pressureof PG-67.4.3.2.2, but less than 20% above the maximumallowable working pressure as shown in the master stamp-ing (PG-106.3).

PG-67.4.3.3 There shall be not less than two pres-sure relief valves and the total rated relieving capacity ofthe pressure relief valves shall be not less than 10% ofthe maximum designed steaming capacity of the boileras determined by the Manufacturer. These pressure reliefvalves may be set above the maximum allowable workingpressure of the parts to which they are connected but shallbe set such that the valves will lift at a pressure no higherthan 20% above the maximum allowable working pressureas shown in the master stamping (PG-106.3).

PG-67.4.3.4 At least two of these pressure reliefvalves shall be equipped with a device that directly trans-mits the valve stem lift action to controls that will stop theflow of fuel and feedwater to the boiler. The control cir-cuitry to accomplish this shall be arranged in a “fail-safe”manner (see Note).

NOTE: “Fail-safe” shall mean a circuitry arranged as either of thefollowing:

(a) Energize to trip: There shall be at least two separate and indepen-dent trip circuits served by two power sources, to initiate and performthe trip action. One power source shall be a continuously charged DCbattery. The second source shall be an AC-to-DC converter connectedto the DC system to charge the battery and capable of performing the tripaction. The trip circuits shall be continuously monitored for availability.

It is not mandatory to duplicate the mechanism that actually stops theflow of fuel and feedwater.

(b) De-energize to trip: If the circuits are arranged in such a way thata continuous supply of power is required to keep the circuits closed andoperating and such that any interruption of power supply will actuate thetrip mechanism, then a single trip circuit and single power supply willbe enough to meet the requirements of this subparagraph.

PG-67.4.3.5 The power supply for all controlsand devices required by PG-67.4.3 shall include at leastone source contained within the same plant as the boilerand which is arranged to actuate the controls and devicescontinuously in the event of failure or interruption of anyother power sources.

PG-67.4.4 When stop valves are installed in thewater-steam flow path between any two sections of aforced-flow steam generator with no fixed steam andwaterline,

PG-67.4.4.1 The power-actuated pressure reliev-ing valve(s) required by PG-67.4.1 shall also receive acontrol impulse to open when the maximum allowableworking pressure of the component, having the lowestpressure level upstream to the stop valve, is exceeded, and

57

PG-67.4.4.2 The pressure relief valves shall belocated to provide the pressure protection requirements inPG-67.4.2 or PG-67.4.3.

PG-67.4.5 A reliable pressure-recording device shallalways be in service and records kept to provide evidenceof conformity to the above requirements.

PG-67.5 The coefficient of discharge of pressure reliefvalves shall be determined by actual steam flow measure-ments at a pressure not more than 3% above the pressureat which the valve is set to relieve and when adjusted forblowdown in accordance with PG-69.1.4. The valves shallbe credited with capacities as determined by the provisionsof PG-69.2.

Pressure relief valves may be used that give any openingup to the full discharge capacity of the area of the openingof the inlet of the valve, provided the movement of a steampressure relief valve is such as not to induce lifting ofwater in the boiler.

For high-temperature water boilers pressure relief valvesshall be used. Such valves shall have a closed bonnet.In addition the pressure relief valves shall be capable ofsatisfactory operation when relieving water at the satura-tion temperature corresponding to the pressure at whichthe valve is set to blow.

PG-68 SUPERHEATER AND REHEATERPG-68.1 Except as permitted in PG-58.3.1, every

attached superheater shall have one or more pressure reliefvalves in the steam flow path between the superheateroutlet and the first stop valve. The location shall be suitablefor the service intended and shall provide the overpressureprotection required. The pressure drop upstream of eachpressure relief valve shall be considered in the determina-tion of set pressure and relieving capacity of that valve. Ifthe superheater outlet header has a full, free steam passagefrom end to end and is so constructed that steam is suppliedto it at practically equal intervals throughout its length sothat there is a uniform flow of steam through the super-heater tubes and the header, the pressure relief valve, orvalves, may be located anywhere in the length of theheader.

PG-68.2 The discharge capacity of the pressure reliefvalve, or valves, on an attached superheater may beincluded in determining the number and size of the pressurerelief valves for the boiler, provided there are no interven-ing valves between the superheater pressure relief valveand the boiler, and provided the discharge capacity of thepressure relief valve, or valves, on the boiler, as distinctfrom the superheater is at least 75% of the aggregate valvecapacity required.

PG-68.3 Every isolable superheater that may be shutoff from the boiler and permit the superheater to become



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2010 SECTION I

a fired pressure vessel and all nonintegral separately firedsuperheaters shall have one or more pressure relief valveshaving a discharge capacity equal to 6 lb/ft2 (29 kg/m2) ofsteam per hour, using the superheater surface measured onthe side exposed to the hot gases. As an alternative theManufacturer may also calculate the minimum pressurerelief valve discharge capacity in lb (kg) of steam per hourfrom the maximum expected heat absorption (as deter-mined by the Manufacturer) in Btu /hr (W), divided by1,000 (646). In the case of electrically heated superheaters,the pressure relief valve capacity shall be based upon 31⁄2 lb(1.6 kg) /hr /kW input. The number of pressure relief valvesinstalled shall be such that the total capacity is at leastequal to that required. Pressure relief valves for separatelyfired superheaters shall be located in accordance with therules of PG-68.1 and the mounting rules of PG-71.

PG-68.4 Every reheater shall have one or more pressurerelief valves, such that the total relieving capacity is atleast equal to the maximum steam flow for which the heateris designed. The capacity of the reheater pressure reliefvalves shall not be included in the required relieving capac-ity for the boiler and superheater.

One or more pressure relief valves with a combinedrelieving capacity not less than 15% of the required totalshall be located along the steam flow path between thereheater outlet and the first stop valve. The pressure dropupstream of the pressure relief valves on the outlet side ofthe reheater shall be considered in determining their setpressure.

PG-68.5 A soot blower connection may be attached tothe same outlet from the superheater or reheater that isused for the pressure relief valve connection.

PG-68.6 Every pressure relief valve used on a super-heater or reheater discharging superheated steam at a tem-perature over 450°F (230°C) shall have a casing, includingthe base, body, and, if applicable, bonnet and spindle, ofsteel, steel alloy, or equivalent heat-resisting material.

The pressure relief valve shall have a flanged inlet con-nection, or a weld-end inlet connection. It shall have theseat and disk of suitable heat erosive and corrosive resistingmaterial, and the spring of direct spring-loaded safetyvalves shall be fully exposed outside of the valve casingso that it shall be protected from contact with the escapingsteam.

PG-68.7 The capacity of a pressure relief valve onsuperheated steam shall be calculated by multiplying thecapacity determined in accordance with PG-69.2 by theappropriate superheat correction factor Ksh, fromTable PG-68.7.

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PG-69 CERTIFICATION OF CAPACITY OFPRESSURE RELIEF VALVES

PG-69.1 Before the Code symbol is applied to anypressure relief valve or power-actuated pressure relievingvalve, the valve manufacturer shall have the relievingcapacity of his pressure relief valves certified in accordancewith the provisions of this paragraph.

PG-69.1.1 Capacity certification tests shall be con-ducted using dry saturated steam. The limits for test pur-poses shall be 98% minimum quality and 20°F (10°C)maximum superheat. Correction from within these limitsmay be made to the dry saturated condition.

PG-69.1.2 Tests shall be conducted at a place thatmeets the requirements of A-312.

PG-69.1.3 Capacity test data reports for eachpressure relief valve design and size, signed by themanufacturer and Authorized Observer witnessingthe tests, together with drawings showing thevalve construction, shall be submitted to theASME designee for review and acceptance.24

PG-69.1.4 Capacity certification tests shall be con-ducted at a pressure that does not exceed the set pressureby 3% or 2 psi (15 kPa), whichever is greater. Pressurerelief valves shall be adjusted so that the blowdown doesnot exceed 4% of the set pressure. For pressure relief valvesset at or below 100 psi (700 kPa), the blowdown shall beadjusted so as not to exceed 4 psi (30 kPa). Pressure reliefvalves used on forced-flow steam generators with no fixedsteam and waterline, and pressure relief valves used onhigh-temperature water boilers shall be adjusted so thatthe blowdown does not exceed 10% of the set pressure.The reseating pressure shall be noted and recorded.

PG-69.1.5 Capacity certification of pilot operatedpressure relief valves may be based on tests without thepilot valves installed, provided prior to capacity tests ithas been demonstrated by test to the satisfaction of theAuthorized Observer that the pilot valve will cause themain valve to open fully at a pressure which does notexceed the set pressure by more than 3% or 2 psi (15 kPa),whichever is greater, and that the pilot valve in combinationwith the main valve will meet all of the requirements ofthis Section.

PG-69.1.6 Pressure relief valves for economizer ser-vice shall also be capacity certified using water at a temper-ature between 40°F and 125°F (4°C and 50°C). Thepressure relief valves shall be tested without change to theadjustments established in PG-69.1.1 to PG-69.1.4.

24 Valve capacities are published in “Pressure Relief Device Certifica-tions.” This publication may be obtained from the National Board ofBoiler and Pressure Vessel Inspectors, 1055 Crupper Ave., Columbus,OH 43299.

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TABLE PG-68.7SUPERHEAT CORRECTION FACTOR, Ksh

Flowing Superheat Correction Factor, Ksh, Total Temperature, °F, of Superheated SteamPressure

(psia) 400 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200

50 0.987 0.957 0.930 0.905 0.882 0.861 0.841 0.823 0.805 0.789 0.774 0.759 0.745 0.732 0.719 0.708 0.696100 0.998 0.963 0.935 0.909 0.885 0.864 0.843 0.825 0.807 0.790 0.775 0.760 0.746 0.733 0.720 0.708 0.697150 0.984 0.970 0.940 0.913 0.888 0.866 0.846 0.826 0.808 0.792 0.776 0.761 0.747 0.733 0.721 0.709 0.697200 0.979 0.977 0.945 0.917 0.892 0.869 0.848 0.828 0.810 0.793 0.777 0.762 0.748 0.734 0.721 0.709 0.698250 . . . 0.972 0.951 0.921 0.895 0.871 0.850 0.830 0.812 0.794 0.778 0.763 0.749 0.735 0.722 0.710 0.698

300 . . . 0.968 0.957 0.926 0.898 0.874 0.852 0.832 0.813 0.796 0.780 0.764 0.750 0.736 0.723 0.710 0.699350 . . . 0.968 0.963 0.930 0.902 0.877 0.854 0.834 0.815 0.797 0.781 0.765 0.750 0.736 0.723 0.711 0.699400 . . . . . . 0.963 0.935 0.906 0.880 0.857 0.836 0.816 0.798 0.782 0.766 0.751 0.737 0.724 0.712 0.700450 . . . . . . 0.961 0.940 0.909 0.883 0.859 0.838 0.818 0.800 0.783 0.767 0.752 0.738 0.725 0.712 0.700500 . . . . . . 0.961 0.946 0.914 0.886 0.862 0.840 0.820 0.801 0.784 0.768 0.753 0.739 0.725 0.713 0.701

550 . . . . . . 0.962 0.952 0.918 0.889 0.864 0.842 0.822 0.803 0.785 0.769 0.754 0.740 0.726 0.713 0.701600 . . . . . . 0.964 0.958 0.922 0.892 0.867 0.844 0.823 0.804 0.787 0.770 0.755 0.740 0.727 0.714 0.702650 . . . . . . 0.968 0.958 0.927 0.896 0.869 0.846 0.825 0.806 0.788 0.771 0.756 0.741 0.728 0.715 0.702700 . . . . . . . . . 0.958 0.931 0.899 0.872 0.848 0.827 0.807 0.789 0.772 0.757 0.742 0.728 0.715 0.703750 . . . . . . . . . 0.958 0.936 0.903 0.875 0.850 0.828 0.809 0.790 0.774 0.758 0.743 0.729 0.716 0.703

800 . . . . . . . . . 0.960 0.942 0.906 0.878 0.852 0.830 0.810 0.792 0.774 0.759 0.744 0.730 0.716 0.704850 . . . . . . . . . 0.962 0.947 0.910 0.880 0.855 0.832 0.812 0.793 0.776 0.760 0.744 0.730 0.717 0.704900 . . . . . . . . . 0.965 0.953 0.914 0.883 0.857 0.834 0.813 0.794 0.777 0.760 0.745 0.731 0.718 0.705950 . . . . . . . . . 0.969 0.958 0.918 0.886 0.860 0.836 0.815 0.796 0.778 0.761 0.746 0.732 0.718 0.705

1000 . . . . . . . . . 0.974 0.959 0.923 0.890 0.862 0.838 0.816 0.797 0.779 0.762 0.747 0.732 0.719 0.706

1050 . . . . . . . . . . . . 0.960 0.927 0.893 0.864 0.840 0.818 0.798 0.780 0.763 0.748 0.733 0.719 0.7071100 . . . . . . . . . . . . 0.962 0.931 0.896 0.867 0.842 0.820 0.800 0.781 0.764 0.749 0.734 0.720 0.7071150 . . . . . . . . . . . . 0.964 0.936 0.899 0.870 0.844 0.821 0.801 0.782 0.765 0.749 0.735 0.721 0.7081200 . . . . . . . . . . . . 0.966 0.941 0.903 0.872 0.846 0.823 0.802 0.784 0.766 0.750 0.735 0.721 0.7081250 . . . . . . . . . . . . 0.969 0.946 0.906 0.875 0.848 0.825 0.804 0.785 0.767 0.751 0.736 0.722 0.709

1300 . . . . . . . . . . . . 0.973 0.952 0.910 0.878 0.850 0.826 0.805 0.786 0.768 0.752 0.737 0.723 0.7091350 . . . . . . . . . . . . 0.977 0.958 0.914 0.880 0.852 0.828 0.807 0.787 0.769 0.753 0.737 0.723 0.7101400 . . . . . . . . . . . . 0.982 0.963 0.918 0.883 0.854 0.830 0.808 0.788 0.770 0.754 0.738 0.724 0.7101450 . . . . . . . . . . . . 0.987 0.968 0.922 0.886 0.857 0.832 0.809 0.790 0.771 0.754 0.739 0.724 0.7111500 . . . . . . . . . . . . 0.993 0.970 0.926 0.889 0.859 0.833 0.811 0.791 0.772 0.755 0.740 0.725 0.711

1550 . . . . . . . . . . . . . . . 0.972 0.930 0.892 0.861 0.835 0.812 0.792 0.773 0.756 0.740 0.726 0.7121600 . . . . . . . . . . . . . . . 0.973 0.934 0.894 0.863 0.836 0.813 0.792 0.774 0.756 0.740 0.726 0.7121650 . . . . . . . . . . . . . . . 0.973 0.936 0.895 0.863 0.836 0.812 0.791 0.772 0.755 0.739 0.724 0.7101700 . . . . . . . . . . . . . . . 0.973 0.938 0.895 0.863 0.835 0.811 0.790 0.771 0.754 0.738 0.723 0.7091750 . . . . . . . . . . . . . . . 0.974 0.940 0.896 0.862 0.835 0.810 0.789 0.770 0.752 0.736 0.721 0.707

1800 . . . . . . . . . . . . . . . 0.975 0.942 0.897 0.862 0.834 0.810 0.788 0.768 0.751 0.735 0.720 0.7051850 . . . . . . . . . . . . . . . 0.976 0.944 0.897 0.862 0.833 0.809 0.787 0.767 0.749 0.733 0.718 0.7041900 . . . . . . . . . . . . . . . 0.977 0.946 0.898 0.862 0.832 0.807 0.785 0.766 0.748 0.731 0.716 0.7021950 . . . . . . . . . . . . . . . 0.979 0.949 0.898 0.861 0.832 0.806 0.784 0.764 0.746 0.729 0.714 0.7002000 . . . . . . . . . . . . . . . 0.982 0.952 0.899 0.861 0.831 0.805 0.782 0.762 0.744 0.728 0.712 0.698

2050 . . . . . . . . . . . . . . . 0.985 0.954 0.899 0.860 0.830 0.804 0.781 0.761 0.742 0.726 0.710 0.6962100 . . . . . . . . . . . . . . . 0.988 0.956 0.900 0.860 0.828 0.802 0.779 0.759 0.740 0.724 0.708 0.6942150 . . . . . . . . . . . . . . . . . . 0.956 0.900 0.859 0.827 0.801 0.778 0.757 0.738 0.722 0.706 0.6922200 . . . . . . . . . . . . . . . . . . 0.955 0.901 0.859 0.826 0.799 0.776 0.755 0.736 0.720 0.704 0.6902250 . . . . . . . . . . . . . . . . . . 0.954 0.901 0.858 0.825 0.797 0.774 0.753 0.734 0.717 0.702 0.687

2300 . . . . . . . . . . . . . . . . . . 0.953 0.901 0.857 0.823 0.795 0.772 0.751 0.732 0.715 0.699 0.6852350 . . . . . . . . . . . . . . . . . . 0.952 0.902 0.856 0.822 0.794 0.769 0.748 0.729 0.712 0.697 0.6822400 . . . . . . . . . . . . . . . . . . 0.952 0.902 0.855 0.820 0.791 0.767 0.746 0.727 0.710 0.694 0.6792450 . . . . . . . . . . . . . . . . . . 0.951 0.902 0.854 0.818 0.789 0.765 0.743 0.724 0.707 0.691 0.6772500 . . . . . . . . . . . . . . . . . . 0.951 0.902 0.852 0.816 0.787 0.762 0.740 0.721 0.704 0.688 0.674

2550 . . . . . . . . . . . . . . . . . . 0.951 0.902 0.851 0.814 0.784 0.759 0.738 0.718 0.701 0.685 0.6712600 . . . . . . . . . . . . . . . . . . 0.951 0.903 0.849 0.812 0.782 0.756 0.735 0.715 0.698 0.682 0.6642650 . . . . . . . . . . . . . . . . . . 0.952 0.903 0.848 0.809 0.779 0.754 0.731 0.712 0.695 0.679 0.6642700 . . . . . . . . . . . . . . . . . . 0.952 0.903 0.846 0.807 0.776 0.750 0.728 0.708 0.691 0.675 0.6612750 . . . . . . . . . . . . . . . . . . 0.953 0.903 0.844 0.804 0.773 0.747 0.724 0.705 0.687 0.671 0.657

2800 . . . . . . . . . . . . . . . . . . 0.956 0.903 0.842 0.801 0.769 0.743 0.721 0.701 0.684 0.668 0.6532850 . . . . . . . . . . . . . . . . . . 0.959 0.902 0.839 0.798 0.766 0.739 0.717 0.697 0.679 0.663 0.6492900 . . . . . . . . . . . . . . . . . . 0.963 0.902 0.836 0.794 0.762 0.735 0.713 0.693 0.675 0.659 0.6452950 . . . . . . . . . . . . . . . . . . . . . 0.902 0.834 0.790 0.758 0.731 0.708 0.688 0.671 0.655 0.6403000 . . . . . . . . . . . . . . . . . . . . . 0.901 0.831 0.786 0.753 0.726 0.704 0.684 0.666 0.650 0.635

3050 . . . . . . . . . . . . . . . . . . . . . 0.899 0.827 0.782 0.749 0.722 0.699 0.679 0.661 0.645 0.6303100 . . . . . . . . . . . . . . . . . . . . . 0.896 0.823 0.777 0.744 0.716 0.693 0.673 0.656 0.640 0.6253150 . . . . . . . . . . . . . . . . . . . . . 0.894 0.819 0.772 0.738 0.711 0.688 0.668 0.650 0.634 0.6203200 . . . . . . . . . . . . . . . . . . . . . 0.889 0.815 0.767 0.733 0.705 0.682 0.662 0.644 0.628 0.614

59



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

TABLE PG-68.7MSUPERHEAT CORRECTION FACTOR, Ksh

Flowing Superheat Correction Factor, Ksh, Total Temperature, °C, of Superheated SteamPressure(MPa) 205 225 250 275 300 325 350 375 400 425 450 475 500 525 550 575 600 625

0.50 0.991 0.968 0.942 0.919 0.896 0.876 0.857 0.839 0.823 0.807 0.792 0.778 0.765 0.752 0.74 0.728 0.717 0.7060.75 0.995 0.972 0.946 0.922 0.899 0.878 0.859 0.841 0.824 0.808 0.793 0.779 0.766 0.753 0.74 0.729 0.717 0.7071.00 0.985 0.973 0.95 0.925 0.902 0.88 0.861 0.843 0.825 0.809 0.794 0.78 0.766 0.753 0.741 0.729 0.718 0.7071.25 0.981 0.976 0.954 0.928 0.905 0.883 0.863 0.844 0.827 0.81 0.795 0.781 0.767 0.754 0.741 0.729 0.718 0.7071.50 . . . . . . 0.957 0.932 0.907 0.885 0.865 0.846 0.828 0.812 0.796 0.782 0.768 0.755 0.742 0.73 0.718 0.708

1.75 . . . . . . 0.959 0.935 0.91 0.887 0.866 0.847 0.829 0.813 0.797 0.782 0.769 0.756 0.743 0.731 0.719 0.7082.00 . . . . . . 0.96 0.939 0.913 0.889 0.868 0.849 0.831 0.814 0.798 0.784 0.769 0.756 0.744 0.731 0.72 0.7082.25 . . . . . . 0.963 0.943 0.916 0.892 0.87 0.85 0.832 0.815 0.799 0.785 0.77 0.757 0.744 0.732 0.72 0.7092.50 . . . . . . . . . 0.946 0.919 0.894 0.872 0.852 0.834 0.816 0.8 0.785 0.771 0.757 0.744 0.732 0.72 0.712.75 . . . . . . . . . 0.948 0.922 0.897 0.874 0.854 0.835 0.817 0.801 0.786 0.772 0.758 0.745 0.733 0.721 0.71

3.00 . . . . . . . . . 0.949 0.925 0.899 0.876 0.855 0.837 0.819 0.802 0.787 0.772 0.759 0.746 0.733 0.722 0.713.25 . . . . . . . . . 0.951 0.929 0.902 0.879 0.857 0.838 0.82 0.803 0.788 0.773 0.759 0.746 0.734 0.722 0.7113.50 . . . . . . . . . 0.953 0.933 0.905 0.881 0.859 0.84 0.822 0.804 0.789 0.774 0.76 0.747 0.734 0.722 0.7113.75 . . . . . . . . . 0.956 0.936 0.908 0.883 0.861 0.841 0.823 0.806 0.79 0.775 0.761 0.748 0.735 0.723 0.7114.00 . . . . . . . . . 0.959 0.94 0.91 0.885 0.863 0.842 0.824 0.807 0.791 0.776 0.762 0.748 0.735 0.723 0.712

4.25 . . . . . . . . . 0.961 0.943 0.913 0.887 0.864 0.844 0.825 0.808 0.792 0.776 0.762 0.749 0.736 0.724 0.7134.50 . . . . . . . . . . . . 0.944 0.917 0.89 0.866 0.845 0.826 0.809 0.793 0.777 0.763 0.749 0.737 0.725 0.7134.75 . . . . . . . . . . . . 0.946 0.919 0.892 0.868 0.847 0.828 0.81 0.793 0.778 0.764 0.75 0.737 0.725 0.7135.00 . . . . . . . . . . . . 0.947 0.922 0.894 0.87 0.848 0.829 0.811 0.794 0.779 0.765 0.751 0.738 0.725 0.7145.25 . . . . . . . . . . . . 0.949 0.926 0.897 0.872 0.85 0.83 0.812 0.795 0.78 0.765 0.752 0.738 0.726 0.714

5.50 . . . . . . . . . . . . 0.952 0.93 0.899 0.874 0.851 0.831 0.813 0.797 0.78 0.766 0.752 0.739 0.727 0.7145.75 . . . . . . . . . . . . 0.954 0.933 0.902 0.876 0.853 0.833 0.815 0.798 0.782 0.767 0.753 0.739 0.727 0.7156.00 . . . . . . . . . . . . 0.957 0.937 0.904 0.878 0.855 0.834 0.816 0.798 0.783 0.768 0.753 0.74 0.727 0.7166.25 . . . . . . . . . . . . 0.96 0.94 0.907 0.88 0.856 0.836 0.817 0.799 0.783 0.768 0.754 0.74 0.728 0.7166.50 . . . . . . . . . . . . 0.964 0.944 0.91 0.882 0.859 0.837 0.818 0.801 0.784 0.769 0.754 0.741 0.729 0.716

6.75 . . . . . . . . . . . . 0.966 0.946 0.913 0.885 0.86 0.839 0.819 0.802 0.785 0.769 0.755 0.742 0.729 0.7177.00 . . . . . . . . . . . . . . . 0.947 0.916 0.887 0.862 0.84 0.82 0.802 0.786 0.77 0.756 0.742 0.729 0.7177.25 . . . . . . . . . . . . . . . 0.949 0.919 0.889 0.863 0.842 0.822 0.803 0.787 0.771 0.756 0.743 0.73 0.7177.50 . . . . . . . . . . . . . . . 0.951 0.922 0.891 0.865 0.843 0.823 0.805 0.788 0.772 0.757 0.744 0.73 0.7187.75 . . . . . . . . . . . . . . . 0.953 0.925 0.893 0.867 0.844 0.824 0.806 0.788 0.772 0.758 0.744 0.731 0.719

8.00 . . . . . . . . . . . . . . . 0.955 0.928 0.896 0.869 0.846 0.825 0.806 0.789 0.773 0.758 0.744 0.732 0.7198.25 . . . . . . . . . . . . . . . 0.957 0.932 0.898 0.871 0.847 0.827 0.807 0.79 0.774 0.759 0.745 0.732 0.7198.50 . . . . . . . . . . . . . . . 0.96 0.935 0.901 0.873 0.849 0.828 0.809 0.791 0.775 0.76 0.746 0.732 0.728.75 . . . . . . . . . . . . . . . 0.963 0.939 0.903 0.875 0.85 0.829 0.81 0.792 0.776 0.76 0.746 0.733 0.7219.00 . . . . . . . . . . . . . . . 0.966 0.943 0.906 0.877 0.852 0.83 0.811 0.793 0.776 0.761 0.747 0.734 0.721

9.25 . . . . . . . . . . . . . . . 0.97 0.947 0.909 0.879 0.853 0.832 0.812 0.794 0.777 0.762 0.747 0.734 0.7219.50 . . . . . . . . . . . . . . . 0.973 0.95 0.911 0.881 0.855 0.833 0.813 0.795 0.778 0.763 0.748 0.734 0.7229.75 . . . . . . . . . . . . . . . 0.977 0.954 0.914 0.883 0.857 0.834 0.814 0.796 0.779 0.763 0.749 0.735 0.722

10.00 . . . . . . . . . . . . . . . 0.981 0.957 0.917 0.885 0.859 0.836 0.815 0.797 0.78 0.764 0.749 0.735 0.72210.25 . . . . . . . . . . . . . . . 0.984 0.959 0.92 0.887 0.86 0.837 0.816 0.798 0.78 0.764 0.75 0.736 0.723

10.50 . . . . . . . . . . . . . . . . . . 0.961 0.923 0.889 0.862 0.838 0.817 0.799 0.781 0.765 0.75 0.737 0.72310.75 . . . . . . . . . . . . . . . . . . 0.962 0.925 0.891 0.863 0.839 0.818 0.799 0.782 0.766 0.751 0.737 0.72411.00 . . . . . . . . . . . . . . . . . . 0.963 0.928 0.893 0.865 0.84 0.819 0.8 0.782 0.766 0.751 0.737 0.72411.25 . . . . . . . . . . . . . . . . . . 0.964 0.93 0.893 0.865 0.84 0.819 0.799 0.781 0.765 0.75 0.736 0.72311.50 . . . . . . . . . . . . . . . . . . 0.964 0.931 0.894 0.865 0.84 0.818 0.798 0.78 0.764 0.749 0.735 0.722

11.75 . . . . . . . . . . . . . . . . . . 0.965 0.932 0.894 0.865 0.839 0.817 0.797 0.78 0.763 0.748 0.734 0.72112.00 . . . . . . . . . . . . . . . . . . 0.966 0.933 0.894 0.864 0.839 0.817 0.797 0.779 0.762 0.747 0.733 0.71912.25 . . . . . . . . . . . . . . . . . . 0.967 0.935 0.895 0.864 0.839 0.816 0.796 0.778 0.761 0.746 0.732 0.71812.50 . . . . . . . . . . . . . . . . . . 0.967 0.936 0.896 0.864 0.838 0.816 0.796 0.777 0.76 0.745 0.731 0.71712.75 . . . . . . . . . . . . . . . . . . 0.968 0.937 0.896 0.864 0.838 0.815 0.795 0.776 0.759 0.744 0.729 0.716

13.00 . . . . . . . . . . . . . . . . . . 0.969 0.939 0.896 0.864 0.837 0.814 0.794 0.775 0.758 0.743 0.728 0.71513.25 . . . . . . . . . . . . . . . . . . 0.971 0.94 0.897 0.864 0.837 0.813 0.792 0.774 0.757 0.741 0.727 0.71313.50 . . . . . . . . . . . . . . . . . . 0.972 0.942 0.897 0.863 0.837 0.813 0.792 0.773 0.756 0.74 0.725 0.71214.00 . . . . . . . . . . . . . . . . . . 0.976 0.946 0.897 0.863 0.835 0.811 0.79 0.771 0.753 0.737 0.723 0.70914.25 . . . . . . . . . . . . . . . . . . 0.978 0.947 0.898 0.862 0.834 0.81 0.789 0.77 0.752 0.736 0.721 0.707

14.50 . . . . . . . . . . . . . . . . . . . . . 0.948 0.898 0.862 0.833 0.809 0.787 0.768 0.751 0.734 0.72 0.70614.75 . . . . . . . . . . . . . . . . . . . . . 0.948 0.898 0.862 0.832 0.808 0.786 0.767 0.749 0.733 0.719 0.70415.00 . . . . . . . . . . . . . . . . . . . . . 0.948 0.899 0.861 0.832 0.807 0.785 0.766 0.748 0.732 0.717 0.70315.25 . . . . . . . . . . . . . . . . . . . . . 0.947 0.899 0.861 0.831 0.806 0.784 0.764 0.746 0.73 0.716 0.70215.50 . . . . . . . . . . . . . . . . . . . . . 0.947 0.899 0.861 0.83 0.804 0.782 0.763 0.745 0.728 0.714 0.7

15.75 . . . . . . . . . . . . . . . . . . . . . 0.946 0.899 0.86 0.829 0.803 0.781 0.761 0.743 0.727 0.712 0.69816.00 . . . . . . . . . . . . . . . . . . . . . 0.945 0.9 0.859 0.828 0.802 0.779 0.759 0.741 0.725 0.71 0.69616.25 . . . . . . . . . . . . . . . . . . . . . 0.945 0.9 0.859 0.827 0.801 0.778 0.757 0.739 0.723 0.708 0.69416.50 . . . . . . . . . . . . . . . . . . . . . 0.945 0.9 0.858 0.826 0.799 0.776 0.756 0.738 0.721 0.706 0.69216.75 . . . . . . . . . . . . . . . . . . . . . 0.944 0.9 0.857 0.825 0.797 0.774 0.754 0.736 0.719 0.704 0.69

60



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I

TABLE PG-68.7MSUPERHEAT CORRECTION FACTOR, Ksh (CONT’D)

Flowing Superheat Correction Factor, Ksh Total Temperature, °C, of Superheated SteamPressure(MPa) 205 225 250 275 300 325 350 375 400 425 450 475 500 525 550 575 600 625

17.00 . . . . . . . . . . . . . . . . . . . . . 0.944 0.9 0.856 0.823 0.796 0.773 0.752 0.734 0.717 0.702 0.68817.25 . . . . . . . . . . . . . . . . . . . . . 0.944 0.9 0.855 0.822 0.794 0.771 0.75 0.732 0.715 0.7 0.68617.50 . . . . . . . . . . . . . . . . . . . . . 0.944 0.9 0.854 0.82 0.792 0.769 0.748 0.73 0.713 0.698 0.68417.75 . . . . . . . . . . . . . . . . . . . . . 0.944 0.9 0.853 0.819 0.791 0.767 0.746 0.728 0.711 0.696 0.68118.00 . . . . . . . . . . . . . . . . . . . . . 0.944 0.901 0.852 0.817 0.789 0.765 0.744 0.725 0.709 0.694 0.679

18.25 . . . . . . . . . . . . . . . . . . . . . 0.945 0.901 0.851 0.815 0.787 0.763 0.742 0.723 0.706 0.691 0.67718.50 . . . . . . . . . . . . . . . . . . . . . 0.945 0.901 0.85 0.814 0.785 0.761 0.739 0.72 0.704 0.689 0.67418.75 . . . . . . . . . . . . . . . . . . . . . 0.945 0.901 0.849 0.812 0.783 0.758 0.737 0.718 0.701 0.686 0.67119.00 . . . . . . . . . . . . . . . . . . . . . 0.946 0.901 0.847 0.81 0.781 0.756 0.734 0.715 0.698 0.683 0.66919.25 . . . . . . . . . . . . . . . . . . . . . 0.948 0.901 0.846 0.808 0.778 0.753 0.732 0.713 0.696 0.681 0.666

19.50 . . . . . . . . . . . . . . . . . . . . . 0.95 0.9 0.844 0.806 0.776 0.75 0.729 0.71 0.693 0.677 0.66319.75 . . . . . . . . . . . . . . . . . . . . . 0.952 0.899 0.842 0.803 0.773 0.748 0.726 0.707 0.69 0.674 0.6620.00 . . . . . . . . . . . . . . . . . . . . . . . . 0.899 0.84 0.801 0.77 0.745 0.723 0.704 0.687 0.671 0.65720.25 . . . . . . . . . . . . . . . . . . . . . . . . 0.899 0.839 0.798 0.767 0.742 0.72 0.701 0.683 0.668 0.65420.50 . . . . . . . . . . . . . . . . . . . . . . . . 0.899 0.837 0.795 0.764 0.738 0.717 0.697 0.68 0.665 0.651

20.75 . . . . . . . . . . . . . . . . . . . . . . . . 0.898 0.834 0.792 0.761 0.735 0.713 0.694 0.677 0.661 0.64721.00 . . . . . . . . . . . . . . . . . . . . . . . . 0.896 0.832 0.79 0.758 0.732 0.71 0.691 0.673 0.658 0.64321.25 . . . . . . . . . . . . . . . . . . . . . . . . 0.894 0.829 0.786 0.754 0.728 0.706 0.686 0.669 0.654 0.6421.50 . . . . . . . . . . . . . . . . . . . . . . . . 0.892 0.826 0.783 0.75 0.724 0.702 0.682 0.665 0.65 0.63621.75 . . . . . . . . . . . . . . . . . . . . . . . . 0.891 0.823 0.779 0.746 0.72 0.698 0.679 0.661 0.646 0.631

22.00 . . . . . . . . . . . . . . . . . . . . . . . . 0.887 0.82 0.776 0.743 0.716 0.694 0.674 0.657 0.641 0.627

PG-69.2 Relieving capacities shall be determined usingone of the following methods.

PG-69.2.1 Three Valve Method. A capacity certifi-cation test is required on a set of three pressure relief valvesfor each combination of size, design, and pressure setting.The capacity of each valve of the set shall fall within arange of ±5% of the average capacity. If one of the threepressure relief valves tested falls outside this range, it shallbe replaced by two valves, and a new average shall becalculated based on all four valves, excluding the replacedvalve. Failure of any of the four capacities to fall withina range of ±5% of the new average shall be cause to refusecertification of that particular valve design.

The rated relieving capacity for each combination ofdesign, size, and test pressure shall be 90% of the averagecapacity.

PG-69.2.2 Slope Method. If a Manufacturer wishesto apply the Code Symbol to a design of pressure reliefvalves, four valves of each combination of pipe size andorifice size shall be tested. These four valves shall be setat pressures that cover the approximate range of pressuresfor which the valve will be used or covering the rangeavailable at the certified test facility that shall conduct thetests. The capacities based on these four tests shall be asfollows:

(a) The slope W/P of the actual measured capacity ver-sus the flow pressure for each test point shall be calculatedand averaged

For steam

slope pWP

pmeasured capacity

absolute flow rating pressure

61

For water

slope pWP

pmeasured capacity

� (flow rating pressure) − (discharge pressure)

All values derived from the testing must fall within ±5%of the average value

minimum slope p 0.95 � average slope

maximum slope p 1.05 � average slope

If the values derived from the testing do not fall betweenthe minimum and maximum slope values, the AuthorizedObserver shall require that additional valves be tested atthe rate of two for each valve beyond the maximum andminimum values with a limit of four additional valves.

For steam applications the relieving capacity to bestamped on the valve shall not exceed 90% of the averageslope times the absolute accumulation pressure

rated slope p 0.90 � average slope

For water applications the relieving capacity shall notexceed 90% of the average slope multiplied by the squareroot of the difference between the flow rating pressure andthe valve discharge pressure.

rated slope p 0.9 � average slope

� �flow rating pressure − discharge pressure


stamped capacity ≤ rated slope (1.03 � set pressure + 14.7)or (set pressure + 2 psi + 14.7), whichever is greater



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(10)

2010 SECTION I

(SI Units)

stamped capacity ≤ rated slope (1.03 � set pressure +0.101) or (set pressure + 0.015 MPa + 0.101), whicheveris greater

PG-69.2.3 Coefficient of Discharge Method. Acoefficient of discharge for the design, K, may be estab-lished for a specific valve design according to the followingprocedure:

(a) For each design, the pressure relief valve manufac-turer shall submit for test at least three valves for each ofthree different sizes (a total of nine valves). Each valve ofa given size shall be set at a different pressure, coveringthe range of pressures for which the valve will be usedor the range available at the facility where the tests areconducted.

For each valve design where the coefficient of dischargehas been determined that is intended to be restricted in lift,the Manufacturer shall have capacity tests conducted onthree valves of different sizes. Each size valve shall betested for capacity at the minimum lift for which certifica-tion is required, and at two intermediate lift points betweenthe full rated lift and minimum lift certification points.Each of the three test valves shall be set at a differentpressure.

For each valve tested, it shall be verified that actualmeasured capacity at restricted lift will equal or exceedthe rated capacity at full rated lift multiplied by the ratioof measured restricted lift to full rated lift.

(b) Tests shall be made on each pressure relief valveto determine its lift at capacity, popping, and blowdownpressures, and actual relieving capacity. An individualcoefficient, KD, shall be established for each valve asfollows:

KD pactual flow

theoretical flowp individual coefficient of discharge

Where actual flow is determined by test and theoreticalflow, WT is calculated by one of the following equations:

For tests with dry saturated steam

For 45 deg seat


WT p 51.5 � �DLP � 0.707

(SI Units)WT p 5.25 � �DLP � 0.707

For flat seat


WT p 51.5 � �DLP

(SI Units)WT p 5.25 � �DLP

62

For nozzle


WT p 51.5 AP

(SI Units)WT p 5.25 AP

For tests with water

For 45 deg seat


WT p 2,407 �DL (0.707)�(P − Pd)w

(SI Units)

WT p 5 092 �DL (0.707)�(P − Pd)w

For flat seat


WT p 2,407 �DL�(P − Pd)w

(SI Units)

WT p 5 092 �DL�(P − Pd)w

For nozzle


WT p 2,407 A�(P − Pd)w

(SI Units)

WT p 5 092 A�(P − Pd)w

where

A p nozzle throat area, in.2 (mm2)D p seat diameter, in. (mm)L p lift at pressure P, in. (mm)P p (1.03 � set pressure + 14.7), psia, or

p (set pressure + 2 + 14.7), psia, whichever is greaterp (1.03 � set pressure + 0.101), MPa, orp (set pressure + 0.014 + 0.101), MPa, whichever

is greaterPd p pressure at discharge of the valve, psia (MPa)

WT p theoretical flow, lb/hr (kg/hr)w p specific weight of water at inlet conditions, lb/ft3

(kg/m3)

To convert lb/hr of water to gal/min of water, multiply thecapacity in lb/hr by 1/500. To convert kg/hr of water toliter/min of water, multiply the capacity in liter/min by 1/60.

The average of the coefficients KD of the nine tests requiredshall be multiplied by 0.90, and this product shall be takenas the coefficient K of that design. All individual coeffi-cients of discharge, KD, shall fall within a range of ±5%



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2010 SECTION I

of the average coefficient found. If a valve fails to meetthis requirement, the Authorized Observer shall requiretwo additional valves to be tested as replacements for eachvalve having an individual coefficient, KD, outside the ±5%range, with a limit of four additional valves. Failure of acoefficient, KD, to fall within ±5% of the new averagevalue, excluding the replaced valve(s), shall be cause torefuse certification of that particular valve design.

The rated relieving capacity of all sizes and set pressuresof a given design, for which K has been established underthe provision of this paragraph, shall be determined by thefollowing equation:

W ≤ WT � K

where

K p coefficient of discharge for the designW p rated relieving capacity, lb /hr (kg/hr)

WT p theoretical flow, defined by the same equationused to determine KD, lb /hr (kg/hr)

The coefficient of discharge for the design shall be notgreater than 0.878 (the product of 0.9 � 0.975). The coeffi-cient shall not be applied to valves whose beta ratio (ratioof valve throat to inlet diameter) lies outside the rangeof 0.15 to 0.75, unless tests have demonstrated that theindividual coefficient of discharge, KD, for valves at theextreme ends of a larger range, is within ±5% of the averagecoefficient, KD.

For designs where the lift is used to determine the flowarea, all valves shall have the same nominal lift to seatdiameter ratio (L/D).

For pressures over 1,500 psig (10.3 MPa) and up to3,200 psig (22.1 MPa), the value of W shall be multipliedby the correction factor


0.1906P − 1,0000.2292P − 1,061

(SI Units)

27.6P − 1 00033.2P − 1 061

For pressures over 3,200 psig (22.1 MPa), the valueof W shall be multiplied by the appropriate supercriticalcorrection factor, Ksc, from Table PG-69.2.3.

PG-69.3 If a manufacturer wishes to apply the Codesymbol to a power-actuated pressure relieving valve underPG-67.4.1, one valve of each combination of inlet pipesize and orifice size to be used with that inlet pipe sizeshall be tested. The valve shall be capacity tested at fourdifferent pressures approximately covering the range ofthe certified test facility on which the tests are conducted.The capacities, as determined by these four tests, shall beplotted against the absolute flow test pressure and a line

63

drawn through these four test points. All points must liewithin ±5% in capacity value of the plotted line and mustpass through 0-0. From the plotted line, the slope of the linedW/dP shall be determined and a factor of (0.90/51.45)�(dW/dP) shall be applied to capacity computations in thesupercritical region at elevated pressures by means of theisentropic flow equation.


W p 1,135.80.9051.45

�dWdP � P

v

(SI Units)

W p 1 135.80.955.25

�dWdP � P

v

where

dW/dP p rate of change of measured capacity withrespect to absolute pressure

P p absolute inlet pressure, psia (MPa)v p inlet specific volume, ft3 /lb (m3/kg)

W p capacity, lb of steam/hr (kg/hr)

NOTE: The constant 1,135.8 is based on a � factor of 1.30, which isaccurate for superheated steam at temperature above approximately 800°F(430°C). In interest of accuracy, other methods of capacity computationsmust be used at temperatures below 800°F (430°C) at supercritical pres-sures.

PG-69.4 Power-actuated pressure relieving valves,having capacities certified in accordance with the provisionof PG-69.3 and computed in accordance with the formulacontained therein, shall be marked as required by PG-110with the computed capacity, corresponding to 3% abovethe full load operating pressure and temperature conditionsat the valve inlet when the valve is operated by the control-ler, and they shall also be stamped with the set pressureof the controller. When the valve is marked as requiredby this paragraph, it shall be the guarantee by the manufac-turer that the valve also conforms to the details of construc-tion herein specified.

PG-69.6 When changes are made in the design of apressure relief valve or power-actuated pressure relievingvalve in such a manner as to affect the flow path, lift,or performance characteristics of the valve, new tests inaccordance with this Section shall be performed.

PG-70 CAPACITY OF PRESSURE RELIEFVALVES

PG-70.1 Subject to the minimum number required byPG-67.1, the number of pressure relief valves requiredshall be determined on the basis of the maximum designed



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2010 SECTION I

(10) TABLE PG-69.2.3SUPERCRITICAL CORRECTION FACTOR, Ksc

Flowing Total Temperature, °F, of Supercritical SteamPressure,

psia 750 800 850 900 950 1,000 1,050 1,100 1,150 1,200

3,208.2 1.059 0.971 0.913 0.872 0.839 0.811 0.788 0.767 0.748 0.731

3,250 1.064 0.975 0.916 0.874 0.841 0.813 0.788 0.767 0.748 0.7313,300 1.070 0.980 0.919 0.876 0.842 0.814 0.790 0.768 0.749 0.7323,350 1.077 0.985 0.922 0.878 0.844 0.815 0.791 0.769 0.750 0.7323,400 1.084 0.990 0.925 0.881 0.846 0.817 0.792 0.770 0.750 0.733

3,450 1.091 0.996 0.929 0.883 0.848 0.818 0.793 0.771 0.751 0.7343,500 1.100 1.002 0.932 0.885 0.849 0.819 0.794 0.772 0.752 0.7343,550 1.109 1.008 0.935 0.888 0.851 0.821 0.795 0.773 0.753 0.7353,600 1.118 1.014 0.939 0.890 0.853 0.822 0.796 0.774 0.754 0.735

3,650 1.129 1.020 0.943 0.893 0.855 0.824 0.797 0.775 0.754 0.7363,700 1.141 1.027 0.946 0.895 0.857 0.825 0.799 0.775 0.755 0.7373,750 1.153 1.034 0.950 0.898 0.859 0.827 0.800 0.776 0.756 0.7373,800 1.168 1.041 0.954 0.900 0.861 0.828 0.801 0.777 0.757 0.738

3,850 1.186 1.048 0.958 0.903 0.862 0.830 0.802 0.778 0.757 0.7393,900 1.205 1.056 0.962 0.906 0.864 0.831 0.803 0.779 0.758 0.7393,950 1.227 1.064 0.966 0.908 0.866 0.833 0.804 0.780 0.759 0.7404,000 1.251 1.072 0.970 0.911 0.868 0.834 0.806 0.781 0.760 0.741

4,050 1.279 1.080 0.974 0.914 0.870 0.836 0.807 0.782 0.760 0.7414,100 1.310 1.089 0.978 0.916 0.872 0.837 0.808 0.783 0.761 0.7424,150 1.343 1.098 0.983 0.919 0.874 0.839 0.809 0.784 0.762 0.7434,200 1.395 1.107 0.987 0.922 0.876 0.840 0.810 0.785 0.763 0.743

4,250 1.444 1.116 0.992 0.925 0.878 0.842 0.812 0.786 0.764 0.7444,300 1.491 1.125 0.997 0.928 0.881 0.844 0.813 0.787 0.765 0.7454,350 1.538 1.135 1.002 0.931 0.883 0.845 0.814 0.788 0.765 0.7454,400 . . . 1.146 1.007 0.934 0.885 0.847 0.815 0.789 0.766 0.746

4,450 . . . 1.157 1.012 0.937 0.887 0.848 0.817 0.790 0.767 0.7464,500 . . . 1.169 1.017 0.940 0.889 0.850 0.818 0.791 0.768 0.7474,550 . . . 1.181 1.022 0.943 0.892 0.852 0.819 0.792 0.768 0.7484,600 . . . 1.194 1.027 0.947 0.894 0.853 0.820 0.793 0.769 0.749

4,650 . . . 1.207 1.033 0.950 0.896 0.855 0.822 0.794 0.770 0.7494,700 . . . 1.220 1.038 0.953 0.898 0.857 0.823 0.795 0.771 0.7504,750 . . . 1.234 1.044 0.957 0.900 0.858 0.824 0.796 0.772 0.7514,800 . . . 1.248 1.050 0.960 0.903 0.860 0.826 0.797 0.773 0.751

4,850 . . . 1.263 1.056 0.963 0.905 0.862 0.827 0.798 0.774 0.7524,900 . . . 1.278 1.062 0.967 0.908 0.863 0.828 0.799 0.774 0.7534,950 . . . 1.294 1.069 0.970 0.910 0.865 0.830 0.800 0.775 0.7535,000 . . . 1.310 1.075 0.974 0.912 0.867 0.831 0.801 0.776 0.754

5,050 . . . 1.326 1.082 0.978 0.915 0.869 0.832 0.803 0.777 0.7555,100 . . . 1.343 1.088 0.981 0.917 0.871 0.834 0.804 0.778 0.7555,150 . . . 1.360 1.095 0.985 0.920 0.872 0.835 0.805 0.779 0.7565,200 . . . 1.377 1.102 0.989 0.922 0.874 0.837 0.806 0.780 0.757

5,250 . . . 1.393 1.109 0.993 0.925 0.876 0.838 0.807 0.780 0.7585,300 . . . 1.411 1.116 0.997 0.927 0.878 0.839 0.808 0.781 0.7585,350 . . . 1.427 1.123 1.001 0.930 0.880 0.841 0.809 0.782 0.7595,400 . . . 1.443 1.131 1.004 0.933 0.882 0.842 0.810 0.783 0.760

5,450 . . . 1.460 1.139 1.009 0.935 0.884 0.844 0.811 0.784 0.7605,500 . . . 1.476 1.146 1.013 0.938 0.886 0.845 0.812 0.785 0.7615,550 . . . 1.491 1.154 1.017 0.941 0.887 0.846 0.813 0.786 0.7625,600 . . . 1.507 1.162 1.021 0.943 0.889 0.848 0.815 0.787 0.763

64



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2010 SECTION I

TABLE PG-69.2.3SUPERCRITICAL CORRECTION FACTOR, Ksc (CONT’D)

Flowing Total Temperature, °F, of Supercritical SteamPressure,

psia 750 800 850 900 950 1,000 1,050 1,100 1,150 1,200

5,650 . . . 1.522 1.171 1.025 0.946 0.891 0.849 0.816 0.788 0.7635,700 . . . 1.536 1.179 1.030 0.949 0.893 0.851 0.817 0.788 0.7645,750 . . . 1.551 1.187 1.034 0.952 0.895 0.852 0.818 0.789 0.7655,800 . . . 1.565 1.195 1.038 0.955 0.897 0.854 0.819 0.790 0.765

5,850 . . . 1.578 1.204 1.043 0.957 0.899 0.855 0.820 0.791 0.7665,900 . . . 1.591 1.212 1.047 0.960 0.901 0.857 0.821 0.792 0.7675,950 . . . 1.603 1.221 1.052 0.963 0.903 0.858 0.823 0.793 0.7686,000 . . . 1.615 1.229 1.057 0.966 0.906 0.860 0.824 0.794 0.768

steaming capacity, as determined by the boiler Manufac-turer, and the relieving capacity marked on the valves bythe manufacturer.

PG-71 MOUNTING OF PRESSURE RELIEFVALVES

PG-71.1 When two or more pressure relief valves areused on a boiler, they may be mounted either separatelyor as twin valves made by placing individual valves onY-bases, or duplex valves having two valves in the samebody casing. Twin valves made by placing individualvalves on Y-bases, or duplex valves having two valves inthe same body, shall be of approximately equal capacity.

When not more than two valves of different sizes aremounted singly the relieving capacity of the smaller valveshall be not less than 50% of that of the larger valve.

PG-71.2 The pressure relief valve or valves shall beconnected to the boiler independent of any other connec-tion, and attached as close as possible to the boiler or thenormal steam flow path, without any unnecessary interven-ing pipe or fitting. Such intervening pipe or fitting shallbe not longer than the face-to-face dimension of the corres-ponding tee fitting of the same diameter and pressure underthe applicable ASME Standard listed in PG-42 and shallalso comply with PG-8 and PG-39. Every pressure reliefvalve shall be connected so as to stand in an upright posi-tion, with spindle vertical. On high-temperature water boil-ers of the watertube forced-circulation type, the valve shallbe located at the boiler outlet.

PG-71.3 The opening or connection between the boilerand the pressure relief valve shall have at least the area ofthe valve inlet. No valve of any description shall be placedbetween the required pressure relief valve or valves andthe boiler, nor on the discharge pipe between the pressurerelief valve and the atmosphere. When a discharge pipe isused, the cross-sectional area shall be not less than the fullarea of the valve outlet or of the total of the areas of the

65

valve outlets, discharging thereinto. It shall be as short andstraight as possible and so arranged as to avoid unduestresses on the valve or valves.

All pressure relief valve discharges shall be so locatedor piped as to be carried clear from running boards orplatforms. Ample provision for gravity drain shall be madein the discharge pipe at or near each pressure relief valve,and where water of condensation may collect. Each valveshall have an open gravity drain through the casing belowthe level of the valve seat. For iron- and steel-bodied valvesexceeding NPS 21⁄2 (DN 65), the drain hole shall be tappednot less than NPS 3⁄8 (DN 10).

Discharge piping from pressure relief valves on high-temperature water boilers shall be provided with adequateprovisions for water drainage as well as the steam venting.

The installation of cast iron bodied pressure relief valvesfor high-temperature water boilers is prohibited.

PG-71.4 If a muffler is used on a pressure relief valve,it shall have sufficient outlet area to prevent back pressurefrom interfering with the proper operation and dischargecapacity of the valve. The muffler plates or other devicesshall be so constructed as to avoid a possibility of restrictionof the steam passages due to deposit. Mufflers shall notbe used on high-temperature water boiler pressure reliefvalves.

When a pressure relief valve is exposed to outdoor ele-ments that may affect operation of the valve, it is permissi-ble to shield the valve with a satisfactory cover. The shieldor cover shall be properly vented and arranged to permitservicing and normal operation of the valve.

PG-71.5 When a boiler is fitted with two or morepressure relief valves on one connection, this connectionto the boiler shall have a cross-sectional area not less thanthe combined areas of inlet connections of all the pressurerelief valves with which it connects and shall also meetthe requirements of PG-71.3.



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2010 SECTION I

(10) TABLE PG-69.2.3MSUPERCRITICAL CORRECTION FACTOR, KSC

Flowing Total Temperature, °C, of Supercritical SteamPressure,

MPa 400 425 450 475 500 525 550 575 600 625 650

22.12 1.056 0.976 0.922 0.883 0.851 0.824 0.801 0.781 0.762 0.745 0.730

22.25 1.058 0.978 0.924 0.884 0.852 0.825 0.802 0.781 0.763 0.746 0.73022.50 1.063 0.982 0.926 0.886 0.853 0.826 0.803 0.782 0.763 0.746 0.73122.75 1.067 0.985 0.929 0.887 0.855 0.827 0.803 0.783 0.764 0.747 0.73123.00 1.072 0.989 0.931 0.889 0.856 0.828 0.804 0.783 0.764 0.747 0.732

23.25 1.077 0.993 0.934 0.891 0.858 0.830 0.805 0.784 0.765 0.748 0.73223.50 1.082 0.997 0.937 0.893 0.859 0.831 0.806 0.785 0.766 0.748 0.73223.75 1.087 1.001 0.939 0.895 0.860 0.832 0.807 0.785 0.766 0.749 0.73324.00 1.093 1.006 0.942 0.897 0.862 0.833 0.808 0.786 0.767 0.749 0.733

24.25 1.099 1.010 0.945 0.899 0.863 0.834 0.809 0.787 0.768 0.750 0.73424.50 1.106 1.014 0.948 0.901 0.865 0.835 0.810 0.788 0.768 0.751 0.73424.75 1.112 1.019 0.950 0.903 0.866 0.836 0.811 0.789 0.769 0.751 0.73525.00 1.120 1.024 0.953 0.905 0.868 0.837 0.812 0.789 0.769 0.752 0.735

25.25 1.128 1.029 0.956 0.907 0.869 0.839 0.813 0.790 0.770 0.752 0.73625.50 1.136 1.034 0.959 0.909 0.871 0.840 0.814 0.791 0.771 0.753 0.73625.75 1.145 1.039 0.962 0.911 0.872 0.841 0.815 0.792 0.771 0.753 0.73726.00 1.155 1.045 0.966 0.913 0.874 0.842 0.816 0.792 0.772 0.754 0.737

26.25 1.166 1.050 0.969 0.915 0.875 0.843 0.817 0.793 0.773 0.754 0.73726.50 1.178 1.056 0.972 0.917 0.877 0.845 0.818 0.794 0.773 0.755 0.73826.75 1.192 1.062 0.975 0.919 0.879 0.846 0.819 0.795 0.774 0.755 0.73827.00 1.206 1.068 0.979 0.921 0.880 0.847 0.820 0.796 0.775 0.756 0.739

27.25 1.222 1.074 0.982 0.924 0.882 0.848 0.820 0.796 0.775 0.756 0.73927.50 1.239 1.081 0.985 0.926 0.883 0.850 0.821 0.797 0.776 0.757 0.74027.75 1.258 1.088 0.989 0.928 0.885 0.851 0.822 0.798 0.777 0.758 0.74028.00 1.278 1.095 0.992 0.930 0.887 0.852 0.824 0.799 0.777 0.758 0.741

28.25 1.300 1.102 0.996 0.933 0.888 0.854 0.825 0.800 0.778 0.759 0.74128.50 1.323 1.109 1.000 0.935 0.890 0.855 0.826 0.801 0.779 0.759 0.74228.75 1.354 1.117 1.004 0.937 0.892 0.856 0.827 0.801 0.779 0.760 0.74229.00 1.390 1.126 1.007 0.940 0.893 0.857 0.828 0.802 0.780 0.760 0.743

29.25 1.424 1.134 1.011 0.942 0.895 0.859 0.829 0.803 0.781 0.761 0.74329.50 1.457 1.143 1.015 0.945 0.897 0.860 0.830 0.804 0.781 0.762 0.74429.75 1.490 1.151 1.019 0.947 0.899 0.861 0.831 0.805 0.782 0.762 0.74430.00 . . . 1.158 1.023 0.950 0.900 0.863 0.832 0.806 0.783 0.763 0.745

30.25 . . . 1.098 1.028 0.952 0.902 0.864 0.833 0.806 0.784 0.763 0.74530.50 . . . 1.083 1.032 0.955 0.904 0.865 0.834 0.807 0.784 0.764 0.74630.75 . . . 1.090 1.036 0.957 0.906 0.867 0.835 0.808 0.785 0.764 0.74631.00 . . . 1.099 1.041 0.960 0.908 0.868 0.836 0.809 0.786 0.765 0.746

31.25 . . . 1.107 1.046 0.963 0.910 0.870 0.837 0.810 0.786 0.766 0.74731.50 . . . 1.115 1.050 0.966 0.911 0.871 0.838 0.811 0.787 0.766 0.74831.75 . . . 1.124 1.055 0.968 0.913 0.872 0.839 0.812 0.788 0.767 0.74832.00 . . . 1.133 1.060 0.971 0.915 0.874 0.840 0.812 0.788 0.767 0.748

32.25 . . . 1.142 1.065 0.974 0.917 0.875 0.841 0.813 0.789 0.768 0.74932.50 . . . 1.151 1.070 0.977 0.919 0.877 0.843 0.814 0.790 0.769 0.75032.75 . . . 1.160 1.075 0.980 0.921 0.878 0.844 0.815 0.791 0.769 0.75033.00 . . . 1.170 1.080 0.983 0.923 0.879 0.845 0.816 0.791 0.770 0.750

33.25 . . . 1.180 1.085 0.986 0.925 0.881 0.846 0.817 0.792 0.770 0.75133.50 . . . 1.190 1.091 0.988 0.927 0.882 0.847 0.818 0.793 0.771 0.75133.75 . . . 1.201 1.096 0.992 0.929 0.884 0.848 0.819 0.793 0.772 0.75234.00 . . . 1.211 1.102 0.995 0.931 0.885 0.849 0.820 0.794 0.772 0.752

66



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2010 SECTION I

TABLE PG-69.2.3MSUPERCRITICAL CORRECTION FACTOR, KSC (CONT’D)

Flowing Total Temperature, °C, of Supercritical SteamPressure,

MPa 400 425 450 475 500 525 550 575 600 625 650

34.25 . . . 1.222 1.108 0.998 0.933 0.887 0.850 0.820 0.795 0.773 0.75334.50 . . . 1.233 1.114 1.001 0.935 0.888 0.852 0.821 0.796 0.773 0.75334.75 . . . 1.244 1.119 1.004 0.937 0.890 0.853 0.822 0.796 0.774 0.75435.00 . . . 1.255 1.125 1.007 0.939 0.891 0.854 0.823 0.797 0.775 0.754

35.25 . . . 1.267 1.131 1.011 0.941 0.893 0.855 0.824 0.798 0.775 0.75535.50 . . . 1.278 1.137 1.014 0.944 0.894 0.856 0.825 0.799 0.776 0.75535.75 . . . 1.290 1.144 1.017 0.946 0.896 0.858 0.826 0.799 0.776 0.75636.00 . . . 1.301 1.150 1.021 0.948 0.898 0.859 0.827 0.800 0.777 0.757

36.25 . . . 1.313 1.156 1.024 0.950 0.899 0.860 0.828 0.801 0.778 0.75736.50 . . . 1.324 1.162 1.027 0.952 0.901 0.861 0.829 0.802 0.778 0.75836.75 . . . 1.336 1.169 1.031 0.955 0.902 0.862 0.830 0.802 0.779 0.75837.00 . . . 1.347 1.175 1.034 0.957 0.904 0.864 0.831 0.803 0.779 0.759

37.25 . . . 1.358 1.182 1.038 0.959 0.906 0.865 0.832 0.804 0.780 0.75937.50 . . . 1.369 1.188 1.042 0.961 0.907 0.866 0.833 0.805 0.781 0.76037.75 . . . 1.380 1.195 1.045 0.964 0.909 0.867 0.834 0.805 0.781 0.76038.00 . . . 1.391 1.201 1.049 0.966 0.910 0.868 0.834 0.806 0.782 0.761

38.25 . . . 1.402 1.208 1.053 0.968 0.912 0.870 0.835 0.807 0.783 0.76138.50 . . . 1.412 1.215 1.056 0.971 0.914 0.871 0.836 0.808 0.783 0.76238.75 . . . 1.422 1.222 1.060 0.973 0.915 0.872 0.837 0.809 0.784 0.76239.00 . . . 1.433 1.228 1.064 0.975 0.917 0.873 0.838 0.809 0.784 0.763

39.25 . . . 1.443 1.235 1.068 0.978 0.919 0.875 0.839 0.810 0.785 0.76339.50 . . . 1.453 1.242 1.072 0.980 0.921 0.876 0.840 0.811 0.786 0.76439.75 . . . 1.463 1.248 1.076 0.983 0.922 0.877 0.841 0.812 0.786 0.76440.00 . . . 1.472 1.255 1.080 0.985 0.924 0.879 0.842 0.812 0.787 0.765

40.25 . . . 1.481 1.262 1.084 0.988 0.926 0.880 0.843 0.813 0.788 0.76540.50 . . . 1.490 1.268 1.088 0.990 0.928 0.881 0.844 0.814 0.788 0.76640.75 . . . 1.499 1.275 1.092 0.993 0.929 0.882 0.845 0.815 0.789 0.76641.00 . . . 1.507 1.282 1.096 0.995 0.931 0.884 0.846 0.816 0.790 0.767

41.25 . . . 1.515 1.288 1.100 0.998 0.933 0.885 0.847 0.816 0.790 0.767

PG-71.6 Pressure relief valves may be attached todrums or headers by welding provided the welding is donein accordance with Code requirements.

PG-71.7 Every boiler shall have proper outlet connec-tions for the required pressure relief valve, or valves, inde-pendent of any other outside steam connection, the areaof opening to be at least equal to the aggregate areas ofinlet connections of all of the pressure relief valves to beattached thereto. An internal collecting pipe, splash plate,or pan may be used, provided the total area for inlet ofsteam thereto is not less than twice the aggregate areas ofthe inlet connections of the attached pressure relief valves.The holes in such collecting pipes shall be at least 1⁄4 in.(6 mm) in diameter and the least dimension in any otherform of opening for inlet of steam shall be 1⁄4 in. (6 mm).

Such dimensional limitations to operation for steam neednot apply to steam scrubbers or driers provided the netfree steam inlet area of the scrubber or drier is at least 10

67

times the total area of the boiler outlets for the pressurerelief valves.

PG-71.8 If pressure relief valves are attached to aseparate steam drum or dome, the opening between theboiler proper and the steam drum or dome shall be notless than required by PG-71.7.

PG-72 OPERATION OF PRESSURE RELIEFVALVES

PG-72.1 Pressure relief valves shall be designed andconstructed to operate without chattering, with a minimumblowdown of 2 psi (15 kPa) or 2% of the set pressure,whichever is greater, and to attain full lift at a pressurenot greater than 3% above their set pressure.

Pressure relief valves used on forced-flow steam genera-tors with no fixed steam and waterline, and pressure reliefvalves used on high-temperature water boilers must be



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marked for these special services by the valve Manufactureror Assembler.

PG-72.2 The set pressure tolerance plus or minus shallnot exceed that specified in the following table:

Tolerance, Plus or MinusSet Pressure, psi (MPa) From Set Pressure

≤ 70 (0.5) 2 psi (15 kPa)70 (0.5) and ≤ 300 (2.1) 3% of set pressure> 300 (2.1) and ≤ 1,000 (7.0) 10 psi (70 kPa)> 1,000 (7.0) 1% of set pressure

PG-72.3 The spring in a pressure relief valve shall notbe reset for any pressure more than 5% above or belowthat for which the valve is marked unless the new settingis within the spring design range established by the manu-facturer or is determined to be acceptable to the manufac-turer.

If the set pressure is to be adjusted within the limitsspecified above, the adjustment shall be performed by themanufacturer, his authorized representative, or an assem-bler. An additional valve data tag identifying the new setpressure, capacity, and date shall be furnished and installed,and the valve shall be resealed.

PG-72.4 If the set pressure of a valve is changed soas to require a new spring, the spring shall be acceptableto the manufacturer. The spring installation and valveadjustment shall be performed by the manufacturer, hisauthorized representative, or an assembler. A new name-plate as described in PG-110 shall be furnished andinstalled, and the valve shall be resealed.

PG-73 MINIMUM REQUIREMENTSFOR PRESSURE RELIEFVALVES

PG-73.1 Permissible Pressure Relief Valves

PG-73.1.1 Pressure relief valves shall be either directspring-loaded safety valves, direct spring-loaded safetyrelief valves, or pilot-operated pressure relief valves.

PG-73.1.2 Power-actuated pressure relieving valvesshall only be used for applications specified in PG-67.4.1.

PG-73.1.3 Deadweight or weighted lever safetyvalves or safety relief valves shall not be used.

PG-73.1.4 Unless otherwise defined, the definitionsrelating to pressure relief devices in ASME PTC 25 shallapply.

PG-73.2 Minimum RequirementsPG-73.2.1 All pressure relief valves shall be so con-

structed that the failure of any part cannot obstruct the freeand full discharge of steam and water from the valve.Pressure relief valves shall have the seat inclined at any

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angle between 45 deg and 90 deg, inclusive, to the center-line of the disk.

PG-73.2.2 The design shall incorporate guidingarrangements necessary to insure consistent operation andtightness.

PG-73.2.3 The spring shall be designed so that thefull lift spring compression shall be no greater than 80%of the nominal solid deflection. The permanent set of thespring (defined as the difference between the free heightand height measured 10 min after the spring has beencompressed solid three additional times after presetting atroom temperature) shall not exceed 0.5% of the free height.

PG-73.2.4 To provide a means for verifying whetherit is free, each safety valve or safety relief valve shallhave a substantial lifting device, which when activated willrelease the seating force on the disk when the valve issubjected to pressure of at least 75% of the set pressure.The lifting device shall be such that it cannot lock or holdthe valve disk in lifted position when the exterior liftingforce is released. Disks of pressure relief valves used onhigh-temperature water boilers shall not be lifted while thetemperature of the water exceeds 200°F (93°C). If it isdesired to lift the valve disk to assure that it is free, thisshall be done when the valve is subjected to a pressure ofat least 75% of the set pressure. Pilot-operated pressurerelief valves shall be provided with either a lifting deviceas described above or means for connecting and applyingpressure to the pilot adequate to verify that the movingparts critical to proper operations are free to move. Forhigh-temperature water boilers, the lifting mechanism shallbe sealed against leakage.

PG-73.2.5 The seat of a pressure relief valve shallbe fastened to the body of the valve in such a way thatthere is no possibility of the seat lifting.

PG-73.2.6 A body drain below seat level shall beprovided in the valve and this drain shall not be pluggedduring or after field installation. For valves exceedingNPS 21⁄2 (DN 65), the drain hole or holes shall be tapped notless than NPS 3⁄8 (DN 10). For valves of NPS 21⁄2 (DN 65) orsmaller, the drain hole shall not be less than 1⁄4 in. (6 mm)in diameter.

PG-73.2.7 In the design of the body of the valve,consideration shall be given to minimizing the effects ofwater deposits.

PG-73.2.8 Valves having screwed inlet or outlet con-nections shall be provided with wrenching surfaces to allowfor normal installation without damaging operating parts.

PG-73.2.9 Means shall be provided in the design ofall valves for use under this Section, for sealing all externaladjustments. Seals shall be installed by the manufacturer,his authorized representative, or an assembler at the timeof the initial adjustment. After spring replacement and/or



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subsequent adjustment, the valve shall be resealed. Sealsshall be installed in such a manner as to prevent changingthe adjustment without breaking the seal and, in addition,shall serve as a means of identifying the manufacturer,his authorized representative, or the assembler making theadjustment.

PG-73.2.10 Valve capacity may be restricted byrestricting the lift of a valve provided the following require-ments are met:

(a) The valve size shall be NPS 3/4 (DN 20) or larger.(b) No changes shall be made in the design of the valve

except to change the valve lift by use of a lift restrainingdevice described in (c) below.

(c) The restriction of valve capacity shall be permittedonly by the use of a lift restraining device which shalllimit valve lift and shall not otherwise interfere with flowthrough the valve. The design of the lift restraining deviceshall be subject to review by an ASME designee.

(d) The lift restraining device shall be designed so that,if adjustable, the adjustable feature can be sealed. Sealsshall be installed by the valve Manufacturer or Assemblerat the time of initial adjustment.

(e) Valves shall not have their lifts restricted to a valueless than 30% of full rated lift, or 0.080 in. (2 mm).

(f) When sizing and selecting valves, the restricted liftnameplate capacity shall be determined by multiplying thecapacity at full rated lift by the ratio of the restricted liftto the full rated lift.

PG-73.2.11 A pressure relief valve over NPS 3(DN 80), used for pressure greater than 15 psig (100 kPa),shall have a flanged inlet connection or a welded inletconnection. The dimensions of the flanges subjected toboiler pressure shall conform to the applicable ASME stan-dards as given in PG-42. The facing shall be similar tothose illustrated in the standard.

PG-73.2.12 The pilot sensing line of pilot-operatedpressure relief valves shall be adequately protected fromfreezing.

PG-73.3 Material SelectionsPG-73.3.1 Cast iron seats and disks are not per-

mitted.

PG-73.3.2 Adjacent sliding surfaces such as guidesand disks or disk holders shall both be of corrosion-resistantmaterial. Springs of corrosion-resistant material or havinga corrosion-resistant coating are required. The seats anddisks of pressure relief valves shall be of suitable materialto resist corrosion by the lading fluid.

NOTE: The degree of corrosion resistance, appropriate to the intendedservice, shall be a matter of agreement between the manufacturer andthe purchaser.

PG-73.3.3 Materials used in bodies and bonnets oryokes shall be listed in Section II, Parts A and B, and

69

identified in Tables 1A and 1B of Section II Part D, aspermitted for Section I construction. Materials used in bodyto bonnet or body to yoke bolting shall be listed in ASMEB16.34. Materials used in all other parts required for thepressure relieving or retaining function shall be

(a) listed in ASME Section II(b) listed in ASTM Specifications (see Note below) or(c) controlled by the manufacturer of the pressure relief

valve by a specification ensuring control of chemical andphysical properties and quality at least equivalent to ASTMStandards (see Note below)

PG-73.3.4 Pressure relief valves may have bronzeparts complying with either SB-61, SB-62, or SB-148,provided the maximum allowable stresses and temperaturesdo not exceed the values given in Table 1B of Section II,Part D, and shall be marked to indicate the class of materialused. Such valves shall not be used on superheaters deliv-ering steam at a temperature over 450°F (230°C) for SB-61and SB-148, and 306°F (150°C) for SB-62, and shall notbe used for high-temperature water boilers.

NOTE: It shall be the manufacturer’s responsibility to ensure that theallowable stresses at temperature meet the requirements of Section II,Part D, Appendix 1, Mandatory Basis for Establishing Stress Values inTables 1A and 1B.

PG-73.4 Inspection of Manufacturing and /orAssembly

PG-73.4.1 A manufacturer shall demonstrate to thesatisfaction of an ASME designee that his manufacturing,production, and test facilities and quality control proce-dures will ensure close agreement between the performanceof random production samples and the performance ofthose valves submitted for capacity certification.

PG-73.4.2 Manufacturing, assembly, inspection, andtest operations including capacity, are subject to inspec-tions at any time by an ASME designee.

PG-73.4.3 A Manufacturer or Assembler may begranted permission to apply the V Code Symbol to produc-tion pressure relief valves capacity-certified in accordancewith PG-69, provided the following tests are successfullycompleted. This permission shall expire on the sixth anni-versary of the date it is initially granted. This permissionmay be extended for 6-yr periods if the following testsare successfully repeated within the 6-mo period beforeexpiration.

(a) Two sample production pressure relief valves of asize and capacity within the capability of an ASME-accepted laboratory shall be selected by an ASME desig-nee. The maximum blowdown for these samples shall notexceed the value specified in the following table:

Set Pressure, psi (kPa) Maximum Blowdown

< 67 (500) 4 psi (30 kPa)≥ 67 (500) and ≤ 250 (1 700) 6% of set pressure> 250 (1 700) and < 375 (2 500) 15 psi (100 kPa)≥ 375 (2 500) 4% of set pressure

(10)



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The blowdown for sample valves designed for use onforced flow steam generators with no fixed steam andwaterline or high-temperature water boilers shall notexceed 10% of the set pressure.

(b) Operational and capacity tests shall be conducted inthe presence of an ASME designee at an ASME-acceptedlaboratory. The valve manufacturer or assembler shall benotified of the time of the test and may have representativespresent to witness the test.

(c) Should any valve fail to relieve at or above its certi-fied capacity or should it fail to meet performance require-ments in PG-72, the test shall be repeated at the rate oftwo replacement valves, selected in accordance withPG-73.4.3(a), for each valve that failed.

(d) Failure of any of the replacement valves to meetcapacity or the performance requirements of this Sectionshall be cause for revocation within 60 days of the authori-zation to use the Code symbol on that particular type ofvalve. During this period, the Manufacturer or assemblershall demonstrate the cause of such deficiency and theaction taken to guard against future occurrence.

PG-73.4.4 Use of the Code Symbol Stamp by anassembler indicates the use of original unmodified parts instrict accordance with the instructions of the manufacturerof the valve.

(a) An assembler may transfer original and unmodifiedpressure relief parts produced by the Manufacturer to otherAssemblers, provided the following conditions are met:

(1) both Assemblers have been granted permissionto apply the V or UV Code Symbol to the specific valvetype in which the parts are to be used

(2) the Quality Control System of the Assemblerreceiving the pressure relief valve parts shall define thecontrols for the procurement and acceptance of those parts

(3) the pressure relief valve parts are appropriatelypackaged, marked, or sealed by the Manufacturer to ensurethat the parts are

(a) produced by the Manufacturer(b) the parts are original and unmodified

(b) However, an assembler may convert original fin-ished parts by either machining to another finished part orapplying a corrosion-resistant coating to valve springs fora specific application under the following conditions:

(1) Conversions shall be specified by the Manufac-turer. Drawings and/or written instructions used for partconversion shall be obtained from the Manufacturer andshall include a drawing or description of the converted partbefore and after the conversion.

(2) The Assembler’s quality control system, asaccepted by a representative from an ASME-designatedorganization, must describe in detail the conversion oforiginal parts, provisions for inspection and acceptance,personnel training, and control of current Manufacturer’sdrawings and/or written instructions.

70

(3) The Assembler must document each use of a con-verted part.

(4) The Assembler must demonstrate to the Manufac-turer the ability to perform each type of conversion. TheManufacturer shall document all authorizations granted toperform part conversions. The Manufacturer and Assem-bler shall maintain a file of such authorizations.

(5) For an Assembler to offer restricted lift valves,the Assembler must demonstrate to the satisfaction of theManufacturer the ability to perform valve lift restrictions.The Manufacturer shall document all authorizationsgranted to restrict the lift of the valves, and shall maintainrecords of the lift restrictions made by the Assembler. TheAssembler shall maintain a file of such authorizations.

(6) At least annually a review shall be performed bythe Manufacturer of an Assembler’s system and conversioncapabilities. The Manufacturer shall document the resultsof these reviews. A copy of this documentation shall bekept on file by the Assembler. The review results shall bemade available to a representative from an ASME desig-nated organization.

NOTE: Within the requirements of PG-73.4 and PG-73.5, a manufac-turer is defined as a person or organization who is completely responsiblefor design, material selection, capacity certification, manufacture of allcomponent parts, assembly, testing, sealing, and shipping of pressurerelief valves certified under this Section.

An assembler is defined as a person or organization who purchases orreceives from a manufacturer the necessary component parts or valvesand assembles, adjusts, tests, seals, and ships pressure relief valves certi-fied under this Section at a geographical location other than and usingfacilities other than those used by the manufacturer.

PG-73.5 Testing by Manufacturers or AssemblersPG-73.5.1 Pressure Testing. Each pressure relief

valve to which the Code Symbol Stamp is to be appliedshall be subjected to the following tests by the Manufac-turer or Assembler:

(a) The pressure-containing parts of each valve shall behydrostatically tested at a pressure at least 1.5 times thedesign pressure of the parts. Parts meeting the followingcriteria shall be exempt from pressure testing:

(1) the applied stress under hydrostatic test conditionsdoes not exceed 50% of the allowable stress; and

(2) the part is not cast or welded.(b) Alternatively, testing may be performed pneumati-

cally at a pressure 1.25 times the design pressure of thepart. Pneumatic testing can be hazardous; it is thereforerecommended that special precautions be taken when con-ducting a pneumatic test.

(c) Testing may be done in the component or assembledcondition.

(d) When the valve is designed for discharging directlyto atmosphere, the valve components downstream of thevalve disk are exempt from pressure testing.

(e) Valve components downstream of the disk and fullycontained within the body are exempt from pressure testing.

(10)



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(f) These tests shall be conducted after all machiningand welding operations on the parts have been completed.

(g) There shall be no sign of leakage.

PG-73.5.2 Every valve shall be tested with steamby the manufacturer or assembler to demonstrate its setpoint and pressure-containing integrity. The blowdowncontrol elements of the pressure relief valve shall be setto the Manufacturer’s specifications.

PG-73.5.2.1 Tests shall be conducted either onequipment that meets the requirements of PG-73.5.6, oron the boiler, by raising the pressure to demonstrate theset pressure.

PG-73.5.2.2 When the valve is beyond the produc-tion test equipment capabilities, an alternative test methodpresented in PG-73.5.2.2.1 or PG-73.5.2.2.2 may be used,provided all of the following conditions are met:

(a) testing the valve at full pressure may cause damageto the valve, or testing of the valve is impractical due toboiler system operational safety considerations

(b) the valve lift has been mechanically verified to meetor exceed the required lift

(c) the blowdown control elements of the safety valveare set to the valve manufacturer’s specification

(d) the valve design is compatible with the alternativetest method selected

PG-73.5.2.2.1 The valve, with its lift temporar-ily restricted during the test, if required to prevent valvedamage, shall be tested on steam to demonstrate setpressure.

PG-73.5.2.2.2 The valve may be fitted with ahydraulic or pneumatic lift assist device and tested onsteam at a pressure less than the valve set pressure. Thelift assist device and test procedure shall be calibrated toprovide the set pressure setting within the tolerance ofPG-72.2.

PG-73.5.3 Leak Test(a) A seat tightness test shall be conducted at maximum

expected operating pressure but at a pressure not exceedingthe reseating pressure of the valve. When being tested, avalve exhibiting no sign of leakage shall be consideredadequately tight.

(b) Closed bonnet pressure relief valves designed fordischarge to a closed system shall be tested with a minimumof 30 psig (200 kPa) air or other gas in the secondarypressure zone. There shall be no sign of leakage.25

PG-73.5.4 A manufacturer or assembler shall havea documented program for the application, calibration, andmaintenance of test gages.

25 The user may specify a higher test pressure commensurate with theback pressure anticipated in service.

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PG-73.5.5 Testing time on steam valves shall besufficient to assure that test results are repeatable and repre-sentative of field performance.

PG-73.5.6 Test fixtures and test drums, where appli-cable, shall be of adequate size and capacity to assure thatthe observed set pressure is consistent with the stampedset pressure within the tolerance required by PG-72.2.

PG-73.6 Design Requirements. At the time of submis-sion of valves for capacity certification or testing in accor-dance with PG-69, the ASME designee has the authorityto review design for conformity with the requirements ofthis Section and to reject or require modification of designsthat do not conform, prior to capacity testing.

PG-73.7 Code Symbol “V” Stamp. Each pressurerelief valve to which the Code “V” symbol (seeFig. PG-105.4) will be applied shall have been fabricatedor assembled by a manufacturer or assembler holding avalid Certificate of Authorization (PG-105.2) and capacitycertified in accordance with the requirements of this Sec-tion. A Certified Individual (CI) shall provide oversight toassure that each use of the Code “V” symbol on a pressurerelief valve is in accordance with the requirements of thisSection, and that each use of the Code “V” symbol isdocumented on a Certificate of Conformance, Form P-8.

PG-73.7.1 Requirements for the Certified Individ-ual (CI). The CI shall

(a) be an employee of the manufacturer or assembler(b) be qualified and certified by the manufacturer or

assembler. Qualifications shall include as a minimum(1) knowledge of the requirements of this Section for

the application of the Code “V” symbol(2) knowledge of the manufacturer’s or assembler’s

quality program(3) training commensurate with the scope, complex-

ity, or special nature of the activities to which oversightis to be provided

(c) have a record, maintained and certified by the manu-facturer or assembler, containing objective evidence of thequalifications of the CI and the training program provided

PG-73.7.2 Duties of the Certified Individual (CI).The CI shall

(a) verify that each item to which the Code “V” symbolis applied has a current capacity certification and meets allapplicable requirements of this Section

(b) review documentation for each lot of items to bestamped to verify, for the lot, that requirements of thisSection have been completed

(c) sign the Certificate of Conformance, Form P-8, priorto release of control of the pressure relief valves

PG-73.7.3 Certificate of Conformance, Form P-8(a) The Certificate of Conformance, Form P-8, shall be

filled out by the manufacturer or assembler and signed by



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the Certified Individual. Multiple duplicate pressure reliefvalves may be recorded as a single entry, provided thevalves are identical and are produced in the same lot.

(b) The manufacturer’s or assembler’s written qualitycontrol program shall include requirements for completionof Certificates of Conformance, Form P-8, and retention, bythe manufacturer or assembler, for a minimum of 5 years.

FABRICATION

PG-75 GENERAL

The fabrication of boilers and parts thereof shall conformto the general fabrication requirements in the followingparagraphs and in addition to the specific requirements forfabrication in the Parts of this Section that pertain to themethods of construction used.

PG-76 CUTTING PLATES AND OTHERSTOCK

PG-76.1 Plates may be cut by machining, punching,shearing, or cutting by the electric arc or gas process,providing enough metal is left at any unfinished edges tomeet the requirements of PG-79.

PG-76.2 When end faces of nozzle or manhole necksare to remain unwelded in the completed vessel, these endfaces shall not be cut by shearing unless at least 1⁄8 in.(3 mm) of additional metal is removed by any method thatwill produce a smooth finish.

PG-77 PLATE IDENTIFICATIONPG-77.1 When the boiler is completed, there shall

remain visible on shell plates, furnace sheets, and heads,one group of the plate manufacturer’s stamps, consistingof the manufacturer’s name, plate identification number,material specification number with grade, class, and typeas appropriate, except that heads containing tube holes andbuttstraps shall have visible at least a sufficient portion ofsuch stamps for identification.

PG-77.2 It is permissible for an authorized representa-tive of the boiler Manufacturer to transfer the markings onthe plate provided a record is made of such transfer. Inlieu of the above and PG-77.1, identification may be byapplying a coded marking traceable to the original requiredmarkings or by recording the required markings usingmethods such as material tabulations or as built illustrationwhich ensure identification of each piece of material duringfabrication and subsequent identification in the completedboiler. Such transfers of markings shall be made prior tocutting, except that the Manufacturer may transfer mark-ings immediately after cutting, provided the control of

72

these transfers is described in his written Quality ControlSystem (A-300). The procedure for making such transfershall be acceptable to the Authorized Inspector.

PG-77.3 An authorized representative of the plate man-ufacturer may duplicate the required stamping on any mate-rial wherever located.

PG-77.4 When plate specification heat treatments arenot performed by the mill, they shall be performed by orunder the control of the fabricator, who shall then placethe letter “T” following the letter “G” in the mill platemarking (see SA-20) to indicate that the material specifica-tion heat treatments have been performed. The fabricatorshall also show by a supplement to the appropriate MillTest Report that the specified heat treatment has been per-formed.

PG-78 REPAIRS OF DEFECTS INMATERIALS

Defects in material may be repaired by the boiler Manu-facturer provided acceptance by the Inspector is firstobtained for the method and extent of repairs. Materialthat cannot be satisfactorily repaired shall be rejected.

PG-79 TUBE HOLES AND ENDS

Tube holes shall be drilled full size from the solid plate,or they may be punched at least 1⁄2 in. (13 mm) smaller indiameter than full size, and then drilled, reamed, or finishedfull size with a rotating cutter. The thermal- or plasma-arc cut holes, when made, shall be sufficiently smaller indiameter than full size, such that subsequent machining tofull size shall completely remove all metal whose mechani-cal and metallurgical properties have been affected as aresult of the thermal- or plasma-arc cutting. Tube holesmay be counterbored where the metal is thicker than thatrequired to get a proper bearing by expanding, so as toform narrow seats into which the tube ends can be properlyexpanded, provided there is space available to permit aproper amount of flare of the tube end.

The sharp edges of tube holes shall be taken off on bothsides of the plate with a file or other tool.

PG-80 PERMISSIBLE OUT-OF-ROUNDNESSOF CYLINDRICAL SHELLS

PG-80.1 Internal Pressure. Finished cylindrical sec-tions of headers, shells, drums, and similar componentsshall be circular at any section within a limit of 1% ofthe mean diameter, based on the differences between themaximum and minimum mean diameters at any section.To determine the difference in diameters, measurementsmay be made on the inside or the outside, and when the



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FIG. PG-80 MAXIMUM PERMISSIBLE DEVIATION FROM A CIRCULAR FORM, e, FOR CYLINDRICAL PARTSUNDER EXTERNAL PRESSURE

1000900

100908070

60

50

40

30

250.05 0.10

800

700600

500

400

300

200

150

0.2 0.3 0.4 0.5

Design Length ÷ Outside Diameter, L /Do

GENERAL NOTES:(a) The above chart applies to cylinders over 24 in. (600 mm) O.D.(b) Use the curves e = 1.0ts or e = 0.2ts, respectively, for points falling above or below those curves.

Ou

tsid

e D

iam

eter

÷ T

hic

knes

s, D

o/t

0.6 0.8 1.0 2 3 4 5 6 7 8 9 10

e = 0.20 t

e = 0.25 t

e = 0.3 t

e = 0.4 t

e = 0.5 t

e = 0.6 t

e = 0.8 t

e = 1.0 t

component is made of plates of unequal thicknesses, themeasurements shall be corrected for the plate thicknessesas they may apply, to determine the diameters at the middleline of the plate thickness.

PG-80.2 External Pressure. Welded cylindrical fur-naces and other cylindrical parts subjected to external pres-sure shall be rolled to practically a true circle with amaximum plus or minus deviation not to exceed the fol-lowing:

(a) For components greater than 24 in. (600 mm) O.D.,the maximum permissible deviation, e, shall be obtainedfrom Fig. PG-80. The symbols L, DO, and tS are as definedin PFT-51.1.1.

(b) For components equal to or less than 24 in. (600 mm)O.D., the maximum deviation shall not exceed 1% ofthe O.D.

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PG-81 TOLERANCE FOR FORMED HEADS

When heads are made to an approximate ellipsoidalshape, the inner surface of such heads must lie outside andnot inside of a true ellipse drawn with the major axis equalto the inside diameter of the head and one-half the minoraxis equal to the depth of the head. The maximum variationfrom this true ellipse shall not exceed 0.0125 times theinside diameter of the head.

PG-82 HOLES FOR STAYSPG-82.1 Holes for threaded stays shall be drilled full

size or punched and subsequently drilled or reamed.Punched holes shall not exceed 1⁄4 in. (6 mm) less than fulldiameter for plates over 5⁄16 in. (8 mm) or 1⁄8 in. (3.2 mm)less than full diameter for plates not exceeding 5⁄16 in.(8 mm) thickness prior to finished drilling or reaming.



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Threaded holes shall be tapped fair and true with a fullthread.

PG-82.2 Holes for welded stays shall be cut and pre-pared in accordance with PW-29.

INSPECTION AND TESTS

PG-90 GENERALPG-90.1 Each boiler, superheater, waterwall, or steel

economizer shall be inspected during construction and aftercompletion by an Authorized Inspector (AI). The AI mayperform inspections at other stages of the work as he maydesignate (PW-46.2). Each Manufacturer or Assembler isrequired to arrange for the services of Authorized Inspec-tors (see Foreword and PG-91) to perform inspections onall of his work within the scope of this Section, whetherperformed in the shop or in the field. Duties of the AIare described elsewhere in this Section and include thefollowing:

PG-90.1.1 Verifying that the Manufacturer orAssembler has a valid ASME Certificate of Authorizationcovering the scope of his Code activities (PG-104.2.1,PG-105.5).

PG-90.1.2 Monitoring compliance with the acceptedQuality Control Program and verifying that any changesmeet the requirements of this Section (PG-105.4, PEB-18,A-300).

PG-90.1.3 Verifying that the Certificate Holder hasthe necessary Code books, Addenda, and Code Cases tocover the work being performed.

PG-90.1.4 Reviewing a selected number of the Man-ufacturer’s design calculations to verify compliance withSection I (PG-90.3).

PG-90.1.5 Witnessing and approving proof tests toestablish Maximum Allowable Working Pressure (MAWP)(A-22).

PG-90.1.6 Verifying that the Certificate Holder hassufficient material control to assure that material used forconstruction complies with the applicable requirements ofthis Section (PG-10, PG-11, PG-105.4, A-302.4).

PG-90.1.7 When cutting plate material into two ormore pieces is necessary, verifying that the CertificateHolder’s controls provide a positive means of identificationto maintain traceability of materials (PG-77.2, A-302.4).

PG-90.1.8 Verifying that the Certificate Holder’spersonnel are examining cut edges before welding(PW-29.3).

PG-90.1.9 Verifying that all welding procedurespecifications, procedure qualification records, welder andwelding operator qualification records conform to the

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requirements of this Section (PW-1.2, PW-28, PW-40.2,PW-47, PW-48, PW-53).

PG-90.1.10 If welded repairs are necessary,accepting the method and extent of repairs and verifyingthat only qualified welding procedures, welders, and weld-ing operators are used (PG-78, PW-40.2, PW-54.2).

PG-90.1.11 Verifying that all required heat treat-ments have been performed and are properly documented(PW-11.3.4, PW-39, PW-49).

PG-90.1.12 Verifying that required nondestructiveexaminations and tests have been performed by qualifiedpersonnel and that the results are properly documented(PG-25.2, PW-11, PW-51, PW-52).

PG-90.1.13 Performing the required inspections andwitnessing hydrostatic tests (PG-99, PW-54).

PG-90.1.14 Verifying that the responsible represen-tative of the Certificate Holder has signed the Data Reportand that it is correct before being signed (PG-104, PG-112,PG-113, PW-1.2.5).

PG-90.1.15 Prior to stamping, verifying that the itemis in compliance with the requirements of this Section.After stamping, verifying that the stamping is correct andthat the nameplate, if used, has been properly attached(PG-106, PG-108, PG-109, PW-1.2.5).

PG-90.3 The Manufacturer is responsible for the prepa-ration of design calculations to show compliance with therules of Section I and his signature on the Manufacturers’Data Report Form shall be considered to include certifica-tion that has been done. The Manufacturer shall makeavailable such design calculations as the AuthorizedInspector may request. The Authorized Inspector has theduty to review a selected number of the Manufacturer’sdesign calculations to verify compliance with Section I.

PG-91 QUALIFICATION OF INSPECTORS

The inspection required by this Section shall be by anInspector employed by an ASME accredited AuthorizedInspection Agency,26 that is, the inspection organizationof a state or municipality of the United States, a Canadianprovince, or of an insurance company authorized to writeboiler and pressure vessel insurance. These Inspectors shallhave been qualified by written examination under the rulesof any state of the United States or province of Canadawhich has adopted the Code.

26 Whenever Authorized Inspection Agency or AIA is used in this Code,it shall mean an Authorized Inspection Agency accredited by ASME inaccordance with the requirements in the latest edition of ASME QAI-1,Qualification for Authorized Inspection.



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PG-93 INSPECTION AND REPAIR OF FLATPLATE IN CORNER JOINTS

PG-93.1 When flat plate greater than 1⁄2 in. (13 mm)thickness is welded to other pressure parts to form a cornerjoint, such as in flat heads [Fig. PG-31, illustrations (g),(i-1), and (i-2)], waterlegs of firebox boilers or combustionchambers of wetback boilers [Fig. A-8, illustrations (l)through (n) and (p)], and the exposed edges of the plateare closer to the edge of the weld than a distance equal tothe thickness of the plate, the peripheral plate edges andany remaining exposed surface of the weld joint prepara-tion shall be examined after welding by either the magneticparticle or liquid penetrant method. When the plate is non-magnetic, only the liquid penetrant method shall be used.The requirements of this paragraph shall not apply to thosejoints when 80% or more of the pressure load is carriedby tubes, stays, or braces, or when the exposed edges ofthe plate are farther from the edge of the weld than adistance equal to the thickness of the plate.

PG-93.2 Laminations, cracks, or other imperfectionsfound during the examination required by PG-93.1 thatwould affect the safety of the vessel shall be repairedin accordance with PG-78. The imperfection(s) may bepursued by any suitable method (grinding, chipping, etc.).The repaired area shall be subjected to the same examina-tion that first revealed the imperfection.

PG-93.3 Methods and acceptance criteria for magneticparticle and liquid penetrant examination shall be in accor-dance with A-260 or A-270, respectively.

PG-99 HYDROSTATIC TEST

Hydrostatic testing of the completed boiler unit shall beconducted in accordance with the following requirements:

After a boiler has been completed (see PG-104), it shallbe subjected to pressure tests using water at not less thanambient temperature, but in no case less than 70°F (20°C).Where required test pressures are specified in this para-graph, whether minimum or maximum pressures, theyapply to the highest point of the boiler system. When theboiler is completed in the Manufacturer’s shop withoutboiler external piping, subsequent hydrostatic testing ofthe boiler external piping shall be the responsibility of anyholder of a valid “S,” “A,” or “PP” stamp. The pressurerelief valves need not be included in the hydrostatic test.The tests shall be made in two stages in the followingsequence:

PG-99.1 Hydrostatic pressure tests shall be applied byraising the pressure gradually to not less than 11⁄2 times themaximum allowable working pressure as shown on thedata report to be stamped on the boiler. No part of theboiler shall be subjected to a general membrane stress

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greater than 90% of its yield strength (0.2% offset) at testtemperature. The primary membrane stress to which boilercomponents are subjected during hydrostatic test shall betaken into account when designing the components. Closevisual inspection for leakage is not required during thisstage.

PG-99.2 The hydrostatic test pressure may then bereduced to the maximum allowable working pressure, asshown on the Data Report, to be stamped on the boilerand maintained at this pressure while the boiler is carefullyexamined. The metal temperature shall not exceed 120°F(50°C) during the close examination.

PG-99.3 A completed forced-flow steam generatorwith no fixed steam and waterline, having pressure partsdesigned for different pressure levels along the path ofwater-steam flow, shall be subjected to a hydrostatic pres-sure test by the above procedure (PG-99.1 and PG-99.2)based upon

PG-99.3.1 For the first stage test (PG-99.1) a hydro-static test pressure of not less than 11⁄2 times the maximumallowable working pressure at the superheater outlet asshown in the master stamping (PG-106.3) but no less than11⁄4 times the maximum allowable working pressure of anypart of the boiler, excluding the boiler external piping.

PG-99.3.2 For the second stage test (PG-99.2) thehydrostatic test pressure may be reduced to not less than themaximum allowable working pressure at the superheateroutlet.

PG-99.4 Test GagesPG-99.4.1 An indicating gage, visible to the operator

controlling the pressure applied, shall be connected to thepressure parts. Hydrostatic head on the gage shall be con-sidered such that the required test pressure is achieved atthe top of the boiler.

PG-99.4.2 Dial pressure gages used in testing shallpreferably have dials graduated over their entire range ofabout double the intended maximum test pressure, but inno case shall the range be less than 11⁄2 times that pressure.The spacing between graduations shall be such that theinspector and the operator controlling the test shall be ableto determine when the required test pressure has beenapplied. Digital pressure gages having a wider range ofpressure readings may be used provided the readings givethe same or greater degree of accuracy as obtained withdial pressure gages.

CERTIFICATION BY STAMPING ANDDATA REPORTS

PG-101 HEATING SURFACE COMPUTATIONPG-101.1 For the stamping required by PG-106, the

heating surface shall be computed as specified in PG-101.1.1 through PG-101.1.3.



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PG-101.1.1 Heating surface, as part of a circulatingsystem in contact on one side with water or wet steambeing heated and on the other side with gas or refractorybeing cooled, shall be measured on the side receiving heat.

PG-101.1.2 Boiler heating surface and other equiva-lent surface outside the furnace shall be measured circum-ferentially plus any extended surface.

PG-101.1.3 Waterwall heating surface and otherequivalent surface within the furnace shall be measured asthe projected tube area (diameter � length) plus anyextended surface on the furnace side. In computing theheating surface for this purpose, only the tubes, fireboxes,shells, tubesheets, and the projected area of headers needto be considered, except that for vertical firetube steamboilers only that portion of the tube surface up to the middleof the gage glass is to be computed.

PG-104 GENERALPG-104.1 The completed boiler unit includes all piping

and piping components as defined in the Preamble.The Manufacturer [see Note (1) below] of any complete

boiler unit to be stamped with the Code symbol has theresponsibility of assuring through proper Code certificationthat all work performed by him or others responsible tohim complies with all requirements of the Code, includingdesign, construction, materials, and workmanship. Withthe exception of field installed boiler external piping, whensome portions of a complete boiler unit are supplied by,or Code work is performed by others not responsible tothe Manufacturer, the Manufacturer has the duty ofobtaining from these other organizations their proper Codecertification, covering such portions of work.

When the Manufacturer furnishes a shop assembledboiler that is complete except for boiler external piping,and the boiler has been hydrostatically tested in the shopand properly stamped with the Manufacturer’s “S” symbol,the subsequent installation in the field of the external pipingwithin the scope of Section I is not by itself considered“field assembly of the boiler” [see Note (2) below].

No Manufacturer or assembler may accept Code respon-sibility for work that falls within the scope of the Code,that is performed by workmen employed by any otherorganization, except through proper Code certification. Theresponsibilities set forth herein relate only to Code compli-ance and are not to be construed as involving contractualrelations or legal liabilities.

NOTES:(1) Boiler Manufacturer or Manufacturer as used in PG-104 or other

paragraphs referenced to this Note may also be an Engineering-Contractor organization with or without fabricating facilities, buthaving the capability of providing a design specification that estab-lishes the pressure and temperature conditions for each componentof a complete boiler unit and of assembling the fabricated parts in

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FIG. PG-105.1 OFFICIAL SYMBOLS FOR STAMPSTO DENOTE THE AMERICAN SOCIETY OFMECHANICAL ENGINEERS’ STANDARD

FOR BOILERS

FIG. PG-105.2 OFFICIALSYMBOL FOR STAMP TODENOTE THE AMERICAN

SOCIETY OF MECHANICALENGINEERS’ STANDARD

FOR ASSEMBLY


SOCIETY OF MECHANICALENGINEERS’ STANDARD

FOR WELDED PIPING

the field with authorization from the Society to use the Code symbolstamp “S” in accordance with the Code provisions in PG-105.3.

(2) When boiler external piping within the scope of Section I is fur-nished by other than the boiler Manufacturer, the boiler Manufac-turer is not responsible for the Code certification of such piping.The organizations that furnish and that install such external pipingby welding shall furnish proper Code certification (PG-104.2) forsuch piping including Manufacturers’ Data Report Form P-4A asrequired by PG-112.2.5 and PG-112.3.

PG-104.2 Proper Code certification refers to the fur-nishing of stamping and Data Reports as evidence to estab-lish the following:

PG-104.2.1 The organization that performed thatportion of the work held an appropriate Certificate ofAuthorization.

PG-104.2.2 By signing and furnishing the appro-priate data report, that organization certified compliancewith Code rules for that portion of the work.

PG-104.2.3 By proper use of the Code symbolstamp, that organization identified the portions of the workcovered by its Data Report Form.

PG-104.2.4 By countersignature on the same DataReport a qualified Inspector confirmed that portion of thework complied with applicable Code rules.

PG-105 CODE SYMBOL STAMPSPG-105.1 Authorization. Except as permitted in

PG-105.5, no organization may assume responsibility forCode construction without having first received from theASME a Certificate of Authorization to use one of the



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2010 SECTION I


SOCIETY OF MECHANICALENGINEERS’ STANDARDFOR BOILER PRESSURE

RELIEF VALVES

Code symbol stamps shown in Figs. PG-105.1 throughPG-105.4. There are six such stamps, defined as follows:

(a) S — power boiler symbol stamp (see Fig. PG-105.1)(b) M — miniature boiler symbol stamp (see Fig. PG-

105.1)(c) E — electric boiler symbol stamp (see Fig. PG-

105.1)(d) A — boiler assembly symbol stamp (see Fig. PG-

105.2)(e) PP — pressure piping symbol stamp (see Fig. PG-

105.3)(f) V — boiler pressure relief valve symbol stamp (see

Fig. PG-105.4)Stamps for applying the Code symbol shall be obtained

from the Society. Each boiler, superheater, waterwall,economizer, or boiler part to which a Code symbol is tobe applied shall be fabricated by a Manufacturer who isin possession of an appropriate Code symbol stamp. ACertificate of Authorization to use the Code symbol “S,”“M,” “E,” “A,” “PP,” or “V” stamp will be granted by theSociety pursuant to the provisions of these paragraphs.

PG-105.2 Application for Certificate of Authoriza-tion. Any organization desiring a Certificate of Authoriza-tion shall apply to the Boiler and Pressure VesselCommittee of the Society, on forms issued by the Society,specifying the stamp desired and the scope of Code activi-ties to be performed. When an organization intends to buildCode items in plants in more than one geographical area,separate applications for each plant or a single applicationlisting the addresses of all such plants may be submitted.Each application shall identify the Authorized InspectionAgency providing Code inspection at each plant. A separateCertificate of Authorization will be prepared and a separatefee charged by the Society for each plant.

Each applicant must agree that each Certificate of Autho-rization and each Code symbol stamp are at all times theproperty of the Society, that they will be used accordingto the rules and regulations of this Section of the Code,and that they will be promptly returned to the Societyupon demand, or when the applicant discontinues the Codeactivities covered by his certificate, or when the Certificateof Authorization has expired and no new certificate hasbeen issued. The holder of a Code symbol stamp shall notallow any other organization to use it.

Authorization to use Code symbol stamps may begranted or withheld by the Society in its absolute discretion.

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If authorization is granted, and the proper administrativefee paid, a Certificate of Authorization evidencing permis-sion to use any such symbol, expiring on the triennialanniversary date thereafter, will be forwarded to the appli-cant. Each such certificate will identify the Code symbolto be used, and the type of shop and/or field operationsfor which authorization is granted (see A-370). The certifi-cate will be signed by the Chairman of the Boiler andPressure Vessel Committee and the Director of Accredita-tion. Six months prior to the date of expiration of any suchcertificate, the applicant must apply for a renewal of suchauthorization and the issuance of a new certificate. TheSociety reserves the absolute right to cancel or refuse torenew such authorization returning pro rata, fees paid forthe unexpired term.

PG-105.3 Agreement With Authorized InspectionAgency. As a condition of obtaining and maintaining aCertificate of Authorization to use the “S,” “M,” “E,” “A,”or “PP” Code symbol stamps, the Manufacturer or Assem-bler must have in force at all times, an inspection contractor agreement with an Authorized Inspection Agency asdefined in PG-91 to provide inspection services. Thisinspection contract is a written agreement between theManufacturer or Assembler and the inspection agency thatspecifies the terms and conditions under which the inspec-tion services are to be furnished and that states the mutualresponsibilities of the Manufacturer or Assembler and theAuthorized Inspectors. The certificate holder shall notifythe Society whenever its agreement with an AuthorizedInspection Agency is cancelled or changed to anotherAuthorized Inspection Agency.

Manufacturers or assemblers of pressure relief valvesare not required to have an inspection agreement with anAuthorized Inspection Agency. A Certificate of Authoriza-tion may be granted to a manufacturer or assembler ofpressure relief valves to use the boiler pressure relief valvesymbol stamp providing such stamp is applied only topressure relief valves that have been capacity certified inaccordance with the requirements of this Section.

PG-105.4 Quality Control System. Any Manufactureror Assembler holding or applying for a Certificate ofAuthorization to use the “S,” “M,” “E,” “A,” “PP,” or “V”stamp shall have, and demonstrate, a quality control systemto establish that all Code requirements including material,design, fabrication, examination (by the Manufacturer),and inspection for boilers and boiler parts (by the Author-ized Inspector) will be met. The quality control systemshall be in accordance with the requirements of A-300.

Before issuance or renewal of a Certificate of Authoriza-tion for use of the “S,” “M,” “E,” “A,” or “PP” stamps,the Manufacturer’s facilities and organization are subjectto a joint review by a representative of his inspectionagency and an individual certified as an ASME designeee



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2010 SECTION I

who is selected by the concerned legal jurisdiction. Whenthe jurisdiction assumes responsibility for leading thereview, it shall have certified that its representative hasmet ASME criteria. A written description or checklist ofthe quality control system which identifies what documentsand what procedures the Manufacturer will use to producea Code item shall be available for review. The purpose ofthe review is to evaluate the applicant’s quality controlsystem and its implementation. The applicant shall demon-strate sufficient administrative and fabrication functions ofthe system to show that he has the knowledge and abilityto produce the Code items covered by his quality controlsystem. Fabrication functions may be demonstrated usingcurrent work, a mock-up, or a combination of the two. Awritten report to the Society shall be made jointly by thejurisdiction and the inspection agency employed by theManufacturer to do his Code inspection. This report is thenreviewed by the Subcommittee on Boiler and PressureVessel Accreditation, which will either issue a Certificateof Authorization or notify the applicant of deficienciesrevealed by the review. In such a case, the applicant willbe given an opportunity to explain or correct these defi-ciencies.

Certificates of Authorization will be endorsed to indicatethe scope of activity authorized. Authorization may includefield operations if the review team determines that theseoperations are adequately described in the quality controlmanual, and this determination is accepted by the Society.

Before issuance or renewal of a Certificate of Authoriza-tion for use of the “V” stamp, the valve manufacturer’sor assembler’s facilities and organization are subject to areview by an ASME designee. A written description orchecklist of the quality control system, which identifiesthe documents and procedures the manufacturer or assem-bler will use to produce Code safety and safety relief valves,shall be available for review. The ASME designee shallmake a written report to the Society, where the Subcommit-tee on Boiler and Pressure Vessel Accreditation will acton it as described above.

The Manufacturer may at any time make changes in thequality control system concerning the methods of achievingresults subject to acceptance by the Authorized Inspector.For manufacturers and assemblers of “V” stamped safetyor safety relief valves, such acceptance shall be by theASME designee.

For those areas where there is no jurisdiction or wherea jurisdiction does not choose to select an ASME designeeto review a vessel or vessel parts manufacturer’s facility,that function shall be performed by an ASME designeeselected by ASME. In either case, the ASME designee shallcertify its representative has met ASME criteria. Where thejurisdiction is the Manufacturer’s inspection agency, thejoint review and joint report shall be made by the jurisdic-tion and another representative designated by the Society.

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PG-105.5 Code Construction Before Receipt of Cer-tificate of Authorization. When used to demonstrate hisquality control system, a Manufacturer may start fabricat-ing Code items before receipt of a Certificate of Authoriza-tion to use a Code symbol stamp under the followingconditions:

(a) The fabrication is done with the participation of theAuthorized Inspector and is subject to his acceptance.

(b) The activity shall have been performed in confor-mance with the applicant’s accepted quality control system.

(c) The item is stamped with the appropriate Code sym-bol and certified once the applicant receives his Certificateof Authorization from the Society.

PG-105.6 Regulations on Use of Code SymbolStamps. The Boiler and Pressure Vessel Committee mayat any time make such regulations concerning the issuanceand use of Code symbol stamps as it deems appropriate,and all such regulations shall become binding upon theholders of any valid Certificates of Authorization.

PG-106 STAMPING OF BOILERSPG-106.1 The Manufacturer shall stamp each boiler,

superheater, waterwall, or steel economizer constructedin compliance with this Section in the presence of theAuthorized Inspector, after the hydrostatic test, in the shopof the Manufacturer, except that in cases where boilers,superheaters, waterwalls, or steel economizers are not com-pleted and hydrostatically tested before shipment, properstamping shall be applied at the shop and the data reportsrequired in PG-112 and PG-113 shall be signed by thesame or different Inspectors who shall indicate the portionsof the inspections made at the shop and the field. Thestamping shall consist of the appropriate Code symbolshown in Fig. PG-105.1, which shall be put on each pieceof equipment listed above in the locations specified inPG-111, except as provided in PG-106.2.

PG-106.2 When the watertube boiler is arranged inte-grally with its economizer, superheater and/or waterwalls,the stamping required in PG-106.1 for such parts as arefabricated by the Manufacturer of the boiler may be com-bined into a single stamping located as specified inPG-111.5. Identifying marks shall be placed on all headersas required in PG-111.10, PG-111.11, and PG-111.12.

PG-106.3 For forced-flow steam generators with nofixed steam and waterline, consisting of groups of pressureparts or components designed at several different levelsof maximum allowable working pressures (PG-21), thestamping, required in PG-106.1 for such parts as are fabri-cated by the Manufacturer of the boiler, shall be combinedinto a single stamping. In addition, whichever Manufac-turer [see PG-104, Note (1)] has the responsibility forassurance of Code certification for a completed boiler unit,



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FIG. PG-106 FORM OF STAMPING

Certified by

(Name of Manufacturer)

(Heating surface, boiler and waterwalls)

Manufacturer’sserial number

(Max. allow. working pressure when built)

(Maximum designed steaming capacity)

Year built

that Manufacturer shall provide a master stamping for thecomplete unit which shall show the maximum allowableworking (minimum design) pressure at the superheater out-let as determined by the Manufacturer as itemPG-106.4.1(c). In no case shall the master stamping pres-sure be more than the maximum allowable working pres-sure of any part of the unit, excluding the steam pipingbetween the boiler and the prime mover. The master stamp-ing shall be located as required in PG-111.5.2.

PG-106.4 In addition to the symbol, the followingitems shall also be stamped with letters and figures at least5⁄16 in. (8 mm) high [5⁄32 in. (4 mm) on miniature boilers ifnecessary], arranged as shown in Fig. PG-106.

PG-106.4.1 Items on Boilers(a) Manufacturer’s serial number(b) certified by (name of Manufacturer)(c) maximum allowable working pressure when built(d) heating surface (or power input for electric boilers)(e) year built(f) maximum designed steaming capacity (or, for high-

temperature water boilers, maximum designed output)

PG-106.4.2 Items on Waterwalls, Superheaters, orSteel Economizers

(a) Manufacturer’s serial number(b) certified by (name of Manufacturer)(c) maximum allowable working pressure when built(d) heating surface (not required for integral superheat-

ers) (rated absorption for an isolable economizer)(e) for isolable or nonintegral separately fired superheat-

ers, heating surface or the minimum pressure relief valvedischarge capacity calculated from the maximum expectedheat absorption (as determined by the Manufacturer)

PG-106.5 For boilers with no pressure retaining partlarger than 16 in. (400 mm) O.D., or for equipmentoperating at temperatures above 800°F (425°C), a cast,etched, or stamped metallic nameplate may be used to

79

provide the data required by PG-106 instead of stampingdirectly on the pressure retaining material. This plate shallbe securely attached to the item it describes. If the attach-ment is by welding, the welding shall meet the requirementsof this Section. The Authorized Inspector shall witness thestamping of the Code symbol and verify that the nameplatehas been attached.

PG-106.6 Each Manufacturer shall furnish, in addition,a metallic plate or plates on which the above data arereproduced for all the items manufactured by him, exceptwhen the original stampings are so located on the com-pleted (or assembled) boiler unit that all will be readilyvisible from one place on the operating floor or platform.These plates, if used, shall be located as specified inPG-111.13. All data on such additional plates, includingthe Code symbol, shall be cast, etched, or stamped andthis marking need not be witnessed by an AuthorizedInspector. The letters and figures on these nameplates shallbe not less than 5⁄32 in. (4 mm) high.

PG-106.7 When the Manufacturer is an EngineeringContractor [see PG-104, Note (1)], either of the sequencesspecified in PG-106.7.1 and PG-106.7.2 may be selectedfor the certification and stamping of the completed boiler.

PG-106.7.1 Certification of Field Assembly Priorto Certification of Engineering Contractor

(a) The Engineering Contractor shall prepare a FormP-3A Master Data Report with the Certification of Engi-neering Contractor portion remaining blank. This MasterData Report, including all associated Partial Data Reportsshall be forwarded to the Assembler.

(b) After the required inspections and the hydrostatictest have been performed, the Assembler and his Author-ized Inspector shall certify the field assembly portion ofForm P-3A. The Assembler shall then forward the com-pleted Form P-3A, including all associated Partial DataReports, to the Engineering Contractor.

(c) The Engineering Contractor shall provide a metallicmaster stamping plate or plates. The letters and figures onthis plate shall be not less than 5⁄32 in. (4 mm) high. Thisplate shall include, in addition to the Code symbol, all thedata required by PG-106.4. Such data, except the Codesymbol, may be cast, etched, or stamped on this plate. TheCode symbol shall be stamped. The stamping of the masterstamping plate shall be in the presence of the EngineeringContractor’s Authorized Inspector after the Inspector hasexamined the Design Specification for the complete boilerunit, verified the plate data, and is satisfied that the Engi-neering Contractor has provided for the construction of thecomplete boiler unit. The Engineering Contractor and hisAuthorized Inspector shall then sign the Certification ofEngineering Contractor portion of Form P-3A.

(d) The Engineering Contractor shall provide theAssembler with the master stamping plate who shall affixit to a location on the boiler as specified in PG-111.13.



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2010 SECTION I

PG-106.7.2 Certification of Engineering Contrac-tor Prior to Certification of Field Assembly

(a) The Engineering Contractor shall provide a metallicmaster stamping plate or plates. The letters and figures onthis plate shall be not less than 5⁄32 in. (4 mm) high. Thisplate shall include, in addition to the Code symbol, all thedata required by PG-106.4. Such data, except the Codesymbol, may be cast, etched, or stamped on this plate. TheCode symbol shall be stamped. The stamping of the masterstamping plate shall be in the presence of the EngineeringContractor’s Authorized Inspector after the inspector hasexamined the Design Specification for the complete boilerunit, verified the plate data, and is satisfied that the Engi-neering Contractor has provided for the construction of thecomplete boiler unit. The Engineering Contractor and hisAuthorized Inspector shall then sign the Certification ofEngineering Contractor portion of Form P-3A in the pres-ence of and when authorized by the Authorized Inspector.

(b) The Engineering Contractor shall provide theAssembler with the master stamping plate and Form P-3AMaster Data Report, including all associated Partial DataReports.

(c) After the required inspections and the hydrostatictest have been performed, the Assembler shall affix themaster stamping plate to the boiler at a location as specifiedin PG-111.13 in the presence of and when authorized byhis Authorized Inspector.

(d) The Assembler and his Authorized Inspector shallthen sign the Certificate of Field Assembly portion of FormP-3A. The Assembler shall then forward the completedForm P-3A, including all associated Partial Data Reports,to the Engineering Contractor.

PG-106.8 Stamping and Marking of PartsPG-106.8.1 When only a part of the boiler is supplied

and the data are recorded on Form P-4, Manufacturer’sPartial Data Report (see PG-112.2.4), the part shall bestamped with

(a) ASME Code Symbol above the word “part”(b) certified by (name of Manufacturer)(c) Manufacturer’s serial number of the part(d) year builtParts may be stamped with the ASME Code Symbol

without being pressure tested prior to shipment (seePG-112 for requirements for documentation and stampingof pressure parts that do not contain pressure retainingwelds).

PG-106.8.2 In lieu of such stamping, small parts [5in. (125 mm) O.D. and under] may be marked with anidentification acceptable to the Inspector (e.g., bar coding,etching, paint stencil, etc.) and traceable to the Form P-4,Manufacturer’s Partial Data Report. Such marking shallbe of a type that will remain visible until the part is installed.The Code symbol stamp is not required.

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PG-106.8.3 Manufacturers with multiple locations,each with its own Certificate of Authorization, may transferboiler parts from one location to another without PartialData Reports, provided the Quality Control Systemdescribes the method of identification, transfer, and receiptof the parts.

PG-106.9 No accessory or part of a boiler may bemarked “ASME” or “ASME Std.” unless so specified inthe Code.

PG-106.10 Shell plates, furnace sheets, and heads shallhave identification stamping in conformance with PG-77.

PG-106.11 The American Society of Mechanical Engi-neers’ standard symbols and the boiler builder’s stampsshall not be covered permanently by insulating or othermaterial.

PG-106.12 Multiple Pressure Steam Generators con-sisting of several sections of heat exchange surfacedesigned for different pressure levels may be consideredas a single boiler and the Manufacturer’s stamping requiredby PG-106.1 combined into a single stamping provided

PG-106.12.1 The different circuits of the boiler arenot intended to be operated separately or independently.

PG-106.12.2 The extent and design of the boilerexternal piping for each circuit shall be established in accor-dance with PG-58.3.

PG-106.12.3 The various circuits shall be separatedfrom each other by providing a stop valve and a checkvalve in the feedwater piping leading to each circuit, inaccordance with PG-58.3.3.

PG-106.12.4 Each circuit shall be given a hydro-static test corresponding to its MAWP, as required byPG-99.

PG-106.12.5 Each circuit shall be stamped with theinformation required by PG-106.4. The stamping shall belocated in accordance with PG-111.

PG-106.12.6 The Manufacturer shall furnish, inaddition, a single metallic plate on which the above dataare reproduced for all of the circuits. This plate shall belocated in accordance with PG-111.13. All data on suchplates shall be cast, etched or stamped. The Code symbolshall be stamped on this plate and shall be witnessed byan Authorized Inspector. The letter and figures on thesenameplates shall be not less than 5⁄32 in. (4 mm) high.

PG-107 FIELD ASSEMBLY

Code responsibility for a completed boiler unit that isfield assembled [excluding the shop assembled boiler withfield installed piping, see PG-104, Note (2)] may beassumed only under the following conditions.



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PG-107.1 By the boiler Manufacturer [see PG-104,Note (1)], provided

PG-107.1.1 Assembly work is performed by work-men employed by the boiler Manufacturer.

PG-107.1.2 Any work performed by others, such aserection of piping, that falls within the scope of the Code,is handled by proper Code certification.

PG-107.1.3 The completed boiler unit is properlystamped with the Manufacturer’s “S” symbol in accordancewith PG-108.1.

PG-107.1.4 Data Reports are prepared in accordancewith PG-113.1.

PG-107.2 Jointly by the boiler Manufacturer and theassembler responsible for performing the hydrostatic testof the completed boiler, signing of the Certificate of FieldAssembly Compliance on the Master Data Report, and forproviding the supplemental stamping in accordance withPG-108.2, provided

PG-107.2.1 Assembly work is performed by work-men employed by the assembler.

PG-107.2.2 The assembler uses his own properlyqualified welding procedures, welders and/or welding oper-ators.

PG-107.2.3 Any work performed in the field byothers, such as erection of boiler external piping or partialassembly of the boiler proper, that falls within the scopeof the Code, is handled by proper Code certification.

(a) Code certification of boiler external piping installedby an organization other than the boiler Manufacturer orassembler shall be provided in accordance with PG-109.

(b) Code certification of work performed by an organi-zation responsible for partial field assembly of a boilershall be provided as follows:

(1) The work performed shall be described on a FormP-3. The form shall be marked as not being the Master DataReport. Lines 1 through 5 of the form shall be completed bythe assembler responsible for partial field assembly of theboiler, except that the words “partial field assembly” areto be inserted on Line 4 instead of the unit identificationand ID numbers. The portion of partial field assemblycompleted by the assembler and the location of the stamp-ing required by PG-107.2.3(b)(3) shall be described onLine 15, Remarks.

(2) The Certificate of Field Assembly Compliance onthe form shall be completed and signed by the assembler.The Certificate of Field Assembly Inspection on the formshall be completed and signed by the assembler’s Author-ized Inspector.

(3) When authorized by the Authorized Inspector, theassembler’s Code symbol together with the assembler’sname, or an acceptable abbreviation, and the words “partialfield assembly” shall be stamped by the assembler on a

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major pressure part assembled as part of the work coveredby the Code certification. If limited space prevents this,the stamping shall be applied near the Manufacturer’sstamping required by PG-106.

PG-107.2.4 The completed boiler unit is properlystamped with the Manufacturer’s “S” symbol and theassembler’s Code symbol in accordance with PG-108.2.

PG-107.2.5 Data Reports are prepared in accordancewith PG-113.2 and such Data Reports clearly define thework completed by the Manufacturer and the assembler.

PG-108 STAMPING FOR FIELD-ASSEMBLEDBOILERS

Field assembly of a completed boiler unit may be madeby anyone possessing a valid Certificate of Authorizationfor a power boiler stamp or an assembly stamp providedresponsibility is assumed in accordance with the require-ments of PG-107. Stamping for field assembled boiler unitsshall be completed as specified in PG-108.1 and PG-108.2.

PG-108.1 When responsibility for the completed boilerunit is assumed under PG-107.1, no additional stampingbeyond that required by PG-106 is necessary.

PG-108.2 When responsibility for the completed boilerunit is assumed under PG-107.2, the Manufacturer’s [seePG-104, Note (1)] stamping shall be supplemented withthe assembler’s stamp, together with the name of the assem-bler or an acceptable abbreviation. This supplementarystamping shall be applied in the field on the boiler nearthe stamping called for by PG-106 when authorized bythe field Inspector after the required inspections and thehydrostatic test of the completed boiler unit. This supple-mentary stamping shall also be reproduced on a nameplateas required by PG-106.6 or PG-106.7 and attached in alocation immediately adjacent to the master stamping plate,as required in PG-111.13.

PG-109 STAMPING OF PRESSURE PIPINGPG-109.1 Boiler external piping, as defined in the Pre-

amble, may be fabricated by a manufacturer other than theManufacturer of the boiler, provided that the manufacturerhas been issued a Certificate of Authorization to use the“S” or “PP” symbol stamp. Boiler external piping may beinstalled by welding by a manufacturer or contractor otherthan the Manufacturer of the boiler, provided such an orga-nization has been issued a Certificate of Authorization touse the “S,” “PP,” or “A” symbol stamp. When boilerexternal piping is installed by welding, the welding, includ-ing the qualification of welding procedures, welders, andwelding operators, shall be done in accordance with theapplicable rules of ASME B31.1. The welding shall be



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inspected by an Authorized Inspector at such stages of thework as he may elect. The organizations which fabricateor install such piping shall furnish proper code certification(PG-104.2) for it including a Manufacturer’s Data ReportForm P-4A as required by PG-112.2.5 and PG-112.3.

PG-109.2 Welded boiler external piping includedwithin the scope of this Code, over NPS 2 (DN 50), shallbe stamped with a Code symbol, together with the manufac-turer’s or contractor’s name and serial number. Such stamp-ing shall be on the pipe, valve, or fitting adjacent to thewelded joint farthest from the boiler. For piping operatingat temperatures above 800°F (425°C) the symbol may bestamped on a nameplate that is irremovably attached bywelding, provided such welding is postweld heat treated,or on a circular metal band at least 1⁄4 in. (6 mm) thick.This band around the pipe shall be secured in such a manneras to prevent it from slipping off during handling andinstallation.

Welded piping NPS 2 (DN 50) or less included withinthe scope of this Code shall be marked with an identifica-tion acceptable to the Inspector and traceable to therequired Data Report. Such marking shall be of a type thatwill remain visible until the piping has been installed.

PG-109.3 A manufacturer in possession of the pressurepiping symbol stamp may

(a) design and fabricate welded piping. Such fabrica-tions shall be stamped and reported on a Form P-4A, Manu-facturer’s Data Report for Fabricated Piping, as called forin PG-112.2.5.

(b) fabricate other parts of boilers, such as superheater,waterwall, or economizer headers, where complete designrequirements are provided by others. Such parts shall bestamped or marked as required by PG-106.8 and reportedon a Form P-4, Manufacturer’s Partial Data Report, ascalled for in PG-112.2.4.

PG-109.4 Mechanically assembled boiler external pip-ing which contains no pressure boundary welds does notrequire stamping, and as such may be assembled by a non-stamp holder. Note that the responsibility for documenta-tion and hydrostatic testing of a mechanically assembledboiler external piping must be assumed by a holder of avalid “S,” “A,” or “PP” stamp (see PG-112.2.5).

PG-110 STAMPING OF BOILER PRESSURERELIEF VALVES

Each pressure relief valve shall be plainly marked withthe required data by the Manufacturer or Assembler (seePG-73.4.4) in such a way that the marking will not beobliterated in service. The marking shall be placed on thevalve or on a nameplate securely fastened to the valve.The Code “V” symbol shall be stamped on the valve or

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nameplate by the Manufacturer or Assembler, as applica-ble. The other required data may be stamped, etched,impressed, or cast on the valve or nameplate. For unitsother than those included below, see PG-4. The markingshall include the following:

(a) the name (or an acceptable abbreviation) of the Man-ufacturer and Assembler, as applicable

(b) Manufacturer’s design or type number(c) NPS (DN) (the nominal pipe size of the valve inlet)(d) set pressure psi (MPa)(e) Capacity

(1) capacity lb/hr (kg/hr) (for saturated steamservice in accordance with PG-69.2) or

(2) capacity lb/hr (kg/hr) at °F (°C) (forsuperheated steam service in accordance with PG-68.7 orsupercritical steam service in accordance withPG-69.2.3) or

(3) capacity gal/min (l/min) at 70°F (20°C) andlb/hr (kg/hr) steam for economizer service in accordancewith PG-69.2

(f) year built, or alternatively, a coding may be markedon the valve such that the valve Manufacturer or Assemblercan identify the year the valve was assembled and tested

(g) ASME symbol as shown in Fig. PG-105.4(h) The pilot of a pilot-operated pressure relief valve

shall be plainly marked by the Manufacturer or Assemblershowing the name of the Manufacturer, the Manufacturer’sdesign or type number, the set pressure in pounds persquare inch (MPa), and the year built, or alternatively,a coding that the Manufacturer can use to identify theyear built.

PG-111 LOCATION OF STAMPINGS

The location of the required stampings shall be as listedbelow. These stampings shall be left uncovered or an easilyremovable marked cover may be provided over the stamp-ing when a boiler is covered with insulation, or jacketed.No piping, boiler appliance, or other obstructions shallinterfere with reading of the stamping.

PG-111.1 Horizontal-return tubular boilers — on thefront head above the central rows of tubes.

PG-111.2 Horizontal-flue boilers — on the front headabove the flues.

PG-111.3 Traction, portable, or stationary boilers ofthe locomotive type or Star watertube boilers — on thefurnace end above the handhole. Or on traction boilers ofthe locomotive type — on the left wrapper sheet forwardof the driving wheel.

PG-111.4 Vertical firetube and vertical submerged tubeboilers — on the shell above the firedoor and handholeopening.



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PG-111.5 Watertube BoilersPG-111.5.1 Drum type — on a head of the steam

outlet drum near and above the manhole.

PG-111.5.2 Forced-flow steam generator with nofixed steam and waterline — the master stamping(PG-106.3) shall be located on a major pressure part,located near the main operating floor where readily visible.The Data Report Form shall record the location of themaster stamping.

PG-111.6 Scotch marine boilers — on either side ofthe shell near the normal water level line and as near aspractical to the front tubesheet.

PG-111.7 Economic boilers — on the front head, abovethe center row of tubes.

PG-111.8 Miniature and electric boilers — on someconspicuous and accessible place on the boiler proper, or ona stamping plate at least 3⁄64 in. (1.2 mm) thick, permanentlyfastened (adhesives prohibited) to the boiler.

PG-111.9 On any of the above types where there isnot sufficient space in the place designated, and for othertypes and new designs — in a conspicuous place on theboiler proper. The Data Report Form shall record the loca-tion of the required stamping.

PG-111.10 Superheaters — on superheater header nearthe outlet. Other headers shall carry identifying marks.

PG-111.11 Economizers — at a handy location onwater inlet header or drums. Other headers shall carryidentifying marks.

PG-111.12 Waterwalls — on one end of a lowerheader. Other headers shall carry identifying marks.

PG-111.13 When required by PG-106.6 and PG-106.7,the Manufacturer [see PG-104, Note (1)] shall furnish anameplate or plates on which the appropriate Code Symboland design data for the scope of his responsibility arepermanently imprinted. The nameplate shall be securelyattached to the front of the boiler, its setting or casing, ata place readily visible from the operating floor or platform.

PG-112 MANUFACTURER’S DATA REPORTFORMS

PG-112.1 Ten types of Manufacturer’s Data ReportForms are shown in the Appendix under the heading “DataReport Forms and Guides” at the end of this Section. Theseforms shall be used by the Manufacturer [see PG-104, Note(1)] to record all the items of a complete boiler unit, inaccordance with the provisions of PG-112.2. When thecertification of the complete boiler unit is accomplishedby more than one Data Report, the principal Data Report(P-2, P-2A, P-3, or P-3A) shall be designated as the MasterData Report (see PG-113).

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For forced-flow steam generators with no fixed steamand waterline consisting of groups of pressure parts orcomponents designed at several different pressure levels,a separate Manufacturer’s Data Report shall clearly identifythe pressure parts at each pressure level and show themaximum allowable working pressure. These several DataReports shall be attached to a Master Data Report (PG-113)that shall clearly identify each component as part of thecomplete unit.

PG-112.2 Types of Data Report Forms. The types ofData Report Forms and the purposes for which they areto be used are specified in PG-112.2.1 through PG-112.2.8.

PG-112.2.1 Form P-2, Manufacturer’s Data Reportfor All Types of Boilers Except Watertube and Electric,shall be used to record all types of boilers other thanwatertube boiler units and parts thereof, which are includedunder Form P-3.

PG-112.2.1.1 Form P-2A, Manufacturer’s DataReport for All Types of Electric Boilers, shall be used torecord all types of electric boilers.

PG-112.2.1.2 Form P-2B, Manufacturer’s DataReport for Electric Superheaters and Reheaters, shall beused to record electric superheaters and reheaters installedexternal to the boiler setting.

PG-112.2.2 Form P-3, Manufacturer’s Data Reportfor Watertube Boilers, Superheaters (except electric),Waterwalls, and Economizers, shall be used to record allof the items comprising a watertube boiler.

The Form P-3 shall also be used to record a superheater,waterwall, or economizer when the design of such an itemis certified by a manufacturer other than the boiler Manu-facturer, or when such an item is to be added to an existingboiler. The item shall be stamped with the ASME “S”symbol and the additional information, as applicable,shown in PG-106.4.2.

Item 10 on Form P-3 shall be used to record other partsconnected at the openings listed in Item 11 if such partsare fabricated of materials or by processes that requireCode inspection. If such parts have not been connectedprior to the hydrostatic test, a notation shall be made underItem 10 reading: “No parts connected to the openings listedin Item 11 except as noted.”

PG-112.2.3 Form P-3A, Engineering-ContractorData Report for a Complete Boiler Unit, shall be usedwhen such an organization assumes the Manufacturer’sCode responsibility as provided for by PG-104, Note (1).This form shall be used to certify Code responsibility forthe design specification of the complete boiler unit, ofwhich the components are individually certified by theirindividual manufacturers in accordance with the Coderules. This form also provides for field assembly certifi-cation.



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PG-112.2.4 Form P-3A shall not be used by a Manu-facturer to provide Code certification for only a portion ofthe complete boiler unit.

PG-112.2.5 Form P-4, Manufacturer’s Partial DataReport, shall be used to record boiler parts requiring inspec-tion and stamping under this Section which are furnished byother than the Manufacturer responsible for the completedboiler, superheater, waterwall, or economizer.

(a) Except as provided in PG-112.2.4(b), Form P-4 shallbe used only to provide supporting data for the informationgiven on the Master Data Report (see PG-113) or on theForm P-3 used to record a superheater, waterwall, or econo-mizer.

(b) When used to record parts furnished to the user ofan existing boiler as replacement or repair parts, Form P-4 is sufficient and need not support a Master Data Report.A copy of the parts Manufacturer’s Form P-4 shall beforwarded to the purchaser.

(c) The parts manufacturer shall indicate under“remarks” the extent to which he has performed the designfunctions. When the parts manufacturer performed only aportion of the design, he shall state which portion of thedesign he has performed.

PG-112.2.6 Form P-4A, Manufacturer’s Data Reportfor Fabricated Piping, shall be used to record all shop orfield-welded boiler external piping that falls within thescope of this Section but is not furnished by the boilerManufacturer. Form P-4B, Manufacturer’s Data Report forField-Installed Mechanically Assembled Piping, shall beused to record all field-installed mechanically assembledboiler external piping. Form P-4B shall be used only forpiping that contains no joints brazed or welded by the fieldinstaller.

PG-112.2.7 Form P-5, Summary Data Report forProcess Steam Generators, may be used by the Manufac-turer [see PG-104, Note (1)] to record all items of field-assembled process steam generators of the waste heat orheat recovery type, comprising one or more drums andone or more arrays of heat exchange surface designed fordifferent pressure levels. All such component items shallbe constructed to the applicable rules of the Code and shallbe certified by individual Data Report Forms executed bythe component manufacturer and the Authorized Inspector.When used, the Summary Data Report Form P-5 shall listall the properly executed data report forms for componentscomprising the complete process steam generator and shallbe attached to the Manufacturer’s Data Report.

PG-112.2.8 When using a print version of a DataReport Form, Form P-6, Manufacturer’s Data Report Sup-plementary Sheet, shall be used to record additional datawhere space was insufficient on a Data Report Form. ThisManufacturer’s Data Report Supplementary Sheet will beattached to the Manufacturer’s Data Report Form where

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used. When using an electronic version of a Data ReportForm, it may be expanded to include all additional data,or Form P-6 may be used in accordance with para. PG-112.2.6.

PG-112.2.9 Form P-7, Manufacturer’s Data Reportfor Pressure Relief Valves, shall be used to record requiredpressure relief valves. Form P-7 shall be used as supportingdata for Form P-2, P-3, or P-3A. Form P-7 is not requiredfor boilers certified on Form P-2A, or for boilers with asingle pressure relief valve when the pressure relief valvesize, set pressure, and capacity [lb/hr (kg/hr)] are includedin the remarks section of Form P-2 or P-3.

PG-112.3 Manufacturer’s Data Reports and all associ-ated Partial Data Reports shall be furnished to the pur-chaser, the inspection agency, and the state, municipal, orprovincial authority at the place of installation. Partial DataReports for pressure parts requiring inspection under thisSection, and which are furnished by other than the Manu-facturer having Code responsibility for the boiler or thesuperheater, waterwall, or economizer, shall be executedby the parts manufacturer and the Inspector in accordancewith the requirements of this Section.

Except as provided in PG-112.2.4(b), the Partial DataReports shall be forwarded, in duplicate, to the Manufac-turer of the boiler or the superheater, waterwall, or econo-mizer. These Partial Data Reports, together with his owninspection, shall be the final Inspector’s authority to witnessthe application of the Code symbol to the boiler or thesuperheater, waterwall, or economizer. The Partial DataReports shall be attached to the associated Form P-2, P-2A, P-3, P-3A, or P-5 by the Manufacturer having Coderesponsibility for the boiler or the superheater, waterwall,or economizer.

PG-112.4 A-350 includes nonmandatory guides to aidin the completion and certification of the Manufacturer’sData Report Forms.

PG-112.5 Multiple Pressure Steam Generators shall bedocumented as indicated in PG-112.5.1 and PG-112.5.2.

PG-112.5.1 Data Report Form P-3 or P-3A shall beused by the Manufacturer as the Master Data Report torecord all items comprising a multiple pressure steam gen-erator of the waste heat or heat recovery type. The MasterData Report shall list all of the properly executed datareport forms for the items comprising the complete steamgenerator unit.

PG-112.5.2 Other forms such as P-3, P-4, P-5, P-6,and P-7 shall be used as necessary to provide and summa-rize supporting information for the Master Data Report.

PG-112.6 Manufacturer’s Partial Data Report Form P-4 and stamping in accordance with PG-106 are neitherrequired nor prohibited for pressure parts that do not con-tain pressure retaining welds (e.g., boiler furnace walls,



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floor panel assemblies, tubes with support or hanger lugs).However, the Manufacturer shall certify that the materialand construction are in accordance with the requirementsof this Section.

PG-112.6.1 Certification may be supplied in theform of bills of material and drawings with a statement ofcompliance or Certificate of Compliance from the Manu-facturer.

PG-112.6.2 The Certification shall state what materi-als were used including size (O.D. and wall thickness)and which edition and addenda of the Code were used toconstruct the parts.

PG-112.6.3 The parts shall be clearly identified withmarkings traceable to the certification. The markings maybe in the form of labels, tags, stamping, paint, or codedidentification.

PG-113 MASTER DATA REPORT FORMPG-113.1 The Master Data Report (using Manufactur-

er’s Data Report Forms P-2, P-2A, P-3, or P-3A, as applica-ble) shall be used by the boiler Manufacturer [see PG-104,Note (1)] to fully document all parts of a complete boilerunit [excluding boiler external piping; see PG-104, Note(2)] as having Code certification in accordance with theCode requirements for design, construction, and work-manship.

PG-113.2 When a field-assembled boiler unit is docu-mented by Data Forms from manufacturers other than theManufacturer [see PG-104, Note (1)] responsible for the

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complete boiler unit, the boiler Manufacturer shall com-plete the applicable Master Data Report Form by recordingthe required data from all supporting Data Report Formsthat are required for the complete boiler unit. All DataForms shall be securely attached to the Master Data Report.The Data Reports shall clearly separate shop fabricationfrom field assembly and in the case of large units, supple-mental sheets may be used to record the information. Thecertificate of shop inspection block and the certificate offield assembly block shall clearly designate the items tobe certified by the Inspector in the shop and those to becertified by the Inspector in the field. The certified DataReports furnished by the several manufacturers shall be theshop or field Inspector’s authority to accept the componentsfabricated by the other manufacturers and included in theconstruction of the complete boiler unit.

PG-113.3 The boiler Manufacturer [see PG-104, Note(1)] shall have the responsibility for distributing copies ofthe complete Master Data Report Form (Data Report FormP-2, P-2A, P-3, or P-3A, as applicable) to the inspectionagency and the required number of proper authorities. TheManufacturer’s written quality control system shall includerequirements for completion of Manufacturer’s DataReports. The Manufacturer shall retain the Manufacturer’sData Reports for a minimum of 5 years.

PG-113.4 When boiler external piping is furnishedby an organization not contractually responsible to theManufacturer [see PG-104, Note (1)], the organizationresponsible for the fabrication and installation of this pipingshall have the responsibility for distributing copies of FormP-4A to the inspection agency and proper authorities.



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PART PWREQUIREMENTS FOR BOILERS

FABRICATED BY WELDING

GENERAL

PW-1 GENERAL

PW-1.1 Scope. The rules in Part PW are applicableto boilers and component parts thereof, including pipingconstructed under the provisions of this Section, that arefabricated by welding and shall be used in conjunctionwith the general requirements in Part PG as well as withthe specific requirements in the applicable Parts of thisSection that pertain to the type of boiler under consider-ation.

PW-1.2 Responsibility. Each Manufacturer1 (Certifi-cate of Authorization holder) is responsible for the weldingdone by his organization and shall establish the proceduresand conduct the tests required in Section IX to qualifythe welding procedures he uses in the construction of theweldments built under Section I and the performance testsof welders2 who apply these procedures. Alternatively,AWS Standard Welding Procedure Specifications that havebeen accepted by Section IX may be used for Section Iconstruction, provided the welding meets the requirementsof this Section. A particular AWS Standard Welding Proce-dure may contain a range for a welding variable whereonly part of the range meets the requirements of this Sec-tion. This could apply to one or more welding variables.The Section I requirements always take precedence. Manu-facturers intending to use AWS Standard Welding Proce-dures shall describe in their Quality Control System(A-302.7) control measures used to assure that the weldingmeets the requirements of this Section and Section IX.Other occurrences of the phrase qualified in accordancewith Section IX in this Part shall be construed to permituse of AWS Standard Welding Procedures accepted bySection IX and controlled as described above. Such weld-ing will ordinarily be done by employees of the Manufac-turer who accepts the responsibility for Code construction

1 Manufacturer includes contractor, assembler, and installer.2 Welder includes welding operator.

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of the boiler or part being welded. Alternatively, the Manu-facturer may perform Code welding using the services ofindividual welders who are not in his employ provided allthe following conditions are met.

PW-1.2.1 All Code construction shall be the respon-sibility of the Manufacturer.

PW-1.2.2 All welding shall be performed in accor-dance with Manufacturer’s Welding Procedure Specifica-tions that have been qualified by the Manufacturer inaccordance with the requirements of Section IX.

PW-1.2.3 All welders shall be qualified by the Man-ufacturer in accordance with the requirements ofQW-301.2, Section IX.

PW-1.2.4 The Manufacturer’s quality control systemshall include as a minimum

PW-1.2.4.1 A requirement for complete andexclusive administrative and technical supervision of allwelders by the Manufacturer.

PW-1.2.4.2 Evidence of the Manufacturer’sauthority to assign and remove welders at his discretionwithout involvement of any other organization.

PW-1.2.4.3 A requirement for Assignment ofWelder identification symbols.

PW-1.2.4.4 Evidence that this program has beenaccepted by the Manufacturer’s Authorized InspectionAgency which provides the inspection service.

PW-1.2.5 The Manufacturer shall be responsible forCode compliance of the weldment including Code SymbolStamping and providing Data Report Forms properly exe-cuted and countersigned by the Authorized Inspector.

PW-1.3 Welding Definitions. For some of the morecommon terms related to welding, refer to QW/QB-492 ofSection IX.

MATERIALSPW-5 GENERAL

PW-5.1 Materials used in welded construction of pres-sure parts shall conform to one of the specifications given



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in Section II and shall be limited to those specificallypermitted in Parts PG, PWT, and PFT and for which allow-able stress values are given in Tables 1A and 1B of SectionII, Part D, for Section I construction and for which weldGroup P-Numbers are assigned in Section IX.

PW-5.2 Carbon or alloy steel having a carbon contentof more than 0.35% shall not be used in welded construc-tion or be shaped by oxygen cutting or other thermal cuttingprocesses.

PW-5.3 Austenitic stainless steel materials joined byelectroslag welding shall be limited to SA-240 Grades 304and 316, SA-182 Grades F304 and F316, and SA-351Grade CF 8.

PW-5.4 Welding electrodes and filler metal shall beselected to provide deposited weld metal of chemical com-position and mechanical properties compatible with thematerials to be joined and the service conditions antici-pated.

PW-5.5 Rimmed and semi-killed steels shall not bejoined by the inertia and continuous drive friction weldingprocesses.

PW-5.6 For pressure retaining welds in 21⁄4Cr-1Momaterials, other than circumferential buttwelds less thanor equal to 31⁄2 in. (89 mm) in outside diameter, whendesign metal temperatures exceed 850°F (455°C), the weldmetal shall have a carbon content greater than 0.05%.

DESIGN

PW-8 GENERAL

The rules in the following paragraphs apply specificallyto the design of boilers and parts thereof that are fabricatedby welding and shall be used in conjunction with the gen-eral requirements for design in Part PG, as well as withthe specific requirements for design in the applicable Partsof this Section that pertain to the type of boiler underconsideration.

PW-9 DESIGN OF WELDED JOINTSPW-9.1 Longitudinal, circumferential, and other joints,

uniting the material used for drums, shells, or other pressureparts, except as otherwise provided in PG-31, PG-39,PW-41, PWT-11, and Part PFT shall be full penetrationbutt welds. The welds should preferably be of the double-welded butt type, but may also be of the single-weldedbutt type with the filler metal added from one side onlywhen made to be the equivalent of the double-weldedbutt joint by providing means for accomplishing completepenetration.

87

FIG. PW-9.1 BUTT WELDING OF PLATES OFUNEQUAL THICKNESS

(a)Preferred method

(center linescoincide)

11

3 3

(b)Permissible

(circumferentialjoints only)

(c)Not

permissible

Tapered oneside only(inside oroutside)

1

3

PW-9.2 Welding Grooves. The dimensions and shapeof the edges to be joined by butt welds shall be such asto permit complete fusion and complete joint penetration.

PW-9.3 Joints Between Materials of Unequal Thick-ness. Except as provided in PW-9.3.2, a tapered transitionsection having a length not less than three times the offsetbetween the adjoining surfaces, as shown in Fig. PW-9.1,shall be provided at joints between materials that differ inthickness by more than one-fourth of the thickness of thethinner material or by more than 1⁄8 in. (3 mm). The transi-tion section may be formed by any process that will providea uniform taper. The weld may be partly or entirely in thetapered section or adjacent to it as indicated in Fig. PW-9.1.

This paragraph is not intended to apply to joint designspecifically provided for elsewhere in this Code or to jointsbetween tubes, between tubes and headers, and betweentubes and tubesheets.

PW-9.3.1 Alignment of Shells and Vessels (Includ-ing Pipe or Tube Used as a Shell). In longitudinal shelljoints, the middle lines of the adjoining thicknesses shallbe in alignment within the fabricating tolerances specifiedin PW-33.

Alternatively, the middle lines of plates of differingthickness may be offset so that the inside or outside diame-ters of the thinner and thicker portions of the shell forma continuous surface, provided the following conditionsare met:

(a) The ratio of the thickness of the thicker plate to thethickness of the thinner plate shall not exceed 2:1.

(b) The maximum design temperature shall not exceed750°F (400°C).



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2010 SECTION I

FIG. PW-9.2 PROHIBITED WELDED JOINT

PW-9.3.2 Circumferential Welds in Tube andPipe. When components of different diameters or thick-nesses are welded together, the transition shall not exceeda slope of 30 deg from the smaller to the larger diameter.The transition may be formed by any process that willprovide a uniform taper. Alignment shall meet the provi-sions of PW-34.

PW-9.4 Prohibited Welded Joints. Corner joints asdepicted in Fig. PW-9.2 are prohibited.

PW-10 HEAT TREATMENT

Vessels and vessel parts shall be preheated and postweldheat treated in accordance with the requirements in PW-38and PW-39.

PW-11 VOLUMETRIC EXAMINATIONOF WELDED BUTT JOINTS

PW-11.1 Welded butt joints requiring volumetricexamination are specified in Table PW-11. Unless TablePW-11 restricts volumetric examination to one method,either the radiographic or the ultrasonic method may beused. Acceptance of the weld shall be determined by themethod selected for the initial examination of the com-pleted weld. If repairs are required, the repairs shall beexamined using the same method by which the unaccept-able imperfections were detected. Subsequent examinationof the weld following acceptance is beyond the require-ments of this Section and shall be a matter of agreementbetween the Manufacturer and the User.

Experience has demonstrated that welded butt joints notrequiring volumetric examination by these rules have givensafe and reliable service even if they contain imperfectionsthat may be disclosed upon further examination. Any exam-ination and acceptance standards beyond the requirementsof this Section are beyond the scope of this Code and shallbe a matter of agreement between the Manufacturer andthe user.

PW-11.2 Definitions. For use with Table PW-11 andelsewhere in this Section, the following definitions apply:

88

butt joint: a joint between two members aligned approxi-mately in the same plane.

circumferential butt weld: includes circumferential weldedbutt joints in drums, headers, pipes, and tubes, and weldedbutt joints attaching formed heads to drums, shells, andheaders.

longitudinal butt weld: includes longitudinal and spiralwelded butt joints in drums, shells, headers, pipes, andtubes; any welded butt joint within a sphere or within aformed or flat head or tube sheet; and welded butt jointsattaching insert-nozzles of the type shown in Fig. PW-16.1, illustrations (q-1) through (q-4).

nondestructive examination (NDE): examination methodsused to verify the integrity of materials and welds in acomponent without damaging its structure or altering itsmechanical properties. NDE may involve surface, subsur-face, and volumetric examination.

NPS: nominal pipe size.

volumetric NDE: a method capable of detecting imperfec-tions that may be located anywhere within the examinedvolume. For Section I construction, volumetric NDE islimited to radiographic (RT) and ultrasonic (UT) examina-tion methods.

PW-11.3 For use with Table PW-11, the size and thick-ness of welded butt joints is defined as the larger andthicker of the two abutting edges after edge preparation.

The geometric unsharpness Ug is defined by the equation

Ug p Fd / D

where

D p distance from source of radiation to the weldd p distance from the source side of the weld to the

filmF p source size; the maximum projected dimension

of the radiating source (or effective focal spot) inthe plane perpendicular to the distance D fromthe weld

Ug p geometric unsharpness

PW-13 HEAD-TO-FLANGE REQUIREMENTS

Dished heads, other than hemispherical, concave to pres-sure to be attached by butt welding, and flanged heads orflanged furnace connections to be fillet welded, shall havea length of flange not less than 1 in. (25 mm) for headsor furnace openings not over 24 in. (600 mm) in externaldiameter and not less than 11⁄2 in. (38 mm) for heads orfurnace openings over 24 in. (600 mm) in diameter.



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2010 SECTION I

TABLE PW-11REQUIRED VOLUMETRIC EXAMINATION OF WELDED BUTT JOINTS

Pressure Part Service Conditions [Note (1)]

Subject to Furnace Radiant Heat Not Subject to Furnace Radiant Heat[Note (2)] [Note (2)]

Butt Weld Type Contains Steam and/or Water Contains Water Contains Steam

Longitudinal all sizes all sizes all sizesand thicknesses and thicknesses and thicknesses

Circumferential welds > NPS 10 (DN 250) > NPS 10 (DN 250) or > NPS 10 (DN 250) orin drums and shells or > 11⁄8 in. (29 mm) thick > 11⁄8 in. (29 mm) thick

> 11⁄8 in. (29 mm) thick

Circumferential welds > NPS 4 (DN 100) or > NPS 10 (DN 250) or > NPS 16 (DN 400) orin pipes, tubes, and > 1⁄2 in. (13 mm) thick > 11⁄8 in. (29 mm) thick > 15⁄8 in. (41 mm) thickheaders

GENERAL NOTES:(a) Unless exempted by this table, all longitudinal and circumferential welded butt joints are to be volumetrically examined throughout their

entire length.(b) Volumetric examination is required when either the size or wall thickness limit is exceeded (i.e., the diameter and thickness limitations apply

independently).(c) Radiographic examination shall be performed in accordance with PW-51.(d) Ultrasonic examination shall be carried out in accordance with PW-52.(e) Personnel performing the volumetric examination required by this table shall be qualified and certified in accordance with PW-50.(f) When any combination of radiographic parameters produces a geometric unsharpness exceeding 0.07 in. (1.8 mm) then UT shall be used.(g) Where the thickness is below 1⁄2 in. (13 mm) then RT shall be used.(h) Both RT and UT examination are required for welds in ferritic materials using the electoslag process. If a grain refining (austenizing) heat

treatment is used, the UT examination shall be performed after the heat treatment is completed. If an austenizing heat treatment is not used,the UT examination shall be done after an intermediate postweld heat treatment or after the final post weld heat treatment is completed.

(i) Both RT and UT examination are required for welds in any material using the inertia or continuous drive friction welding process.(j) For electric boilers volumetric examination is not required when the maximum allowable working pressure is ≤ 100 psig (700 kPa) and the

shell I.D. is ≤ 16 in. (400 mm) (see PEB-9.1).(k) For firetube boilers, volumetric examination is not required for

(1) longitudinal welded butt joints in furnaces made with the addition of filler metal, provided a bend test of a sample of the welded jointfor each section of the furnace meets the requirements of PW-53

(2) circumferential welded butt joints in furnaces (see PFT-14)(3) butt welds and corner joints meeting the requirements of PFT-21.1 through PFT-21.3 for waterlegs, furnaces, and fireboxes

(l) For miniature boilers, volumetric examination is not required (see PMB-9).(m) Volumetric examination is not required for the longitudinal weld in ERW products that comply with an acceptable material specification when

used for construction within the limitations of PG-9.5.

NOTES:(1) Service conditions and pressure part contents are as determined by the designer.(2) A weld will not be considered subject to radiant heat from the furnace when in a portion of a pressure part that has five or more rows of

tubes between it and the furnace.

89

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2010 SECTION I

PW-14 OPENINGS IN OR ADJACENTTO WELDS

Any type of opening that meets the requirements forcompensation given in PG-32 through PG-44 may belocated in a welded joint.

PW-15 WELDED CONNECTIONSPW-15.1 Nozzles, other connections, and their com-

pensation may be attached to vessels by arc or gas welding.Sufficient weld and compensation shall be provided oneither side of the plane through the center of the opening,parallel to the longitudinal axis of the vessel, to developthe required strength, as prescribed in PG-37, in shearor tension, whichever is applicable (see Fig. PW-15 forexample calculations, where, if a fillet weld has unequallegs, the value of WL1 or WL2 shall be taken as the lengthof the shorter leg).

PW-15.1.1 The stress correction factors in PW-15.2shall apply to all welds.

PW-15.1.2 The strength of fillet welds shall be basedon one-half the area subjected to shear, computed on theaverage diameter of the weld.

PW-15.1.3 The strength of groove welds shall bebased on one-half the area subjected to shear or tension,as applicable, computed using the minimum weld depthdimension in the direction under consideration.

PW-15.1.6 The strength calculations for nozzleattachment welds are not required for the weld configura-tions shown in Fig. PW-16.1, illustrations (a) through (c),(g), (h), (o), (q-1) through (q-4), (u-1), (v-1), (w-1), (y),and (z).

PW-15.2 Stress Values for Weld Metal. The allowablestress values for groove and fillet welds in percentages ofstress values for the vessel material are as follows:

Material Percentage

Groove-weld tension 74%Groove-weld shear 60%Fillet-weld shear 49%

NOTE: These values are obtained by combining the following factors:871⁄2% for combined end and side loading, 80% for shear strength, andthe applicable joint efficiency factors.

PW-15.3 Compensation plates and saddles of nozzlesattached to the outside of a vessel shall be provided withat least one telltale hole [maximum size 1⁄4 in. (6 mm) pipetap] that may be tapped for a preliminary compressed-airand soapsuds test for tightness of welds that seal off theinside of the vessel. These telltale holes shall be left openwhen the vessel is in service.

PW-15.4 Figure PW-16.1 illustrates some types offusion welded connections which are acceptable.

90

When end faces of nozzle or manhole necks are to remainunwelded in the completed vessel, these end faces shallnot be cut by shearing unless at least 1⁄8 in. (3 mm) ofadditional metal is removed by any method that will pro-duce a smooth finish.

PW-16 MINIMUM REQUIREMENTSFOR ATTACHMENT WELDS

PW-16.1 General. Except as permitted in PW-16.5,PW-16.6, and PW-16.7, nozzles and other connections toshells, drums, and headers shall be attached by full penetra-tion welds applied from one or both sides, partial penetra-tion welds applied from both sides, fillet welds appliedfrom both sides, or fillet and partial penetration weldson opposite sides. In addition to the strength calculationsrequired in PG-37, the location and minimum size of attach-ment welds for nozzles and other connections shall con-form to the requirements in this paragraph.

PW-16.2 Nomenclature. The symbols used in thisparagraph and in Figs. PW-16.1 and PW-16.2 are definedas follows:

t p thickness of vessel shell or headtc p not less than the smaller of 1⁄4 in. (6 mm) or

0.7tmin (inside corner welds may be further lim-ited by a lesser length of projection of thenozzle wall beyond the inside face of the ves-sel wall)

tl p thickness of lug, hanger, or bracket, as shownin Fig. PW-16.2

tmin p the smaller of 3⁄4 in. (19 mm) or the thicknessof either of the weld parts joined by a fillet,single bevel, or single J-weld

tn p thickness of nozzle walltw p dimension of partial penetration attachment

welds (fillet, single bevel, or single J), mea-sured as shown in Fig. PW-16.1

t1 + t2 ≥ 11⁄4 tmin measured as shown in Fig. PW-16.1,in., both t1 and t2 shall each be not less thanthe smaller of 1⁄4 in. (6 mm) or 0.7tmin

PW-16.3 All welding shall be equivalent to thatrequired under the rules within this Section. Volumetricexamination of attachment welds may be omitted exceptas specifically required in other paragraphs of this Code,and except for inserted-type nozzles similar to those illus-trated in Fig. PW-16.1, illustrations (q-1) through (q-4).

PW-16.4 Fittings shown in Fig. PW-16.1, illustrations(u-2), (v-2), (w-2), and (x) not exceeding NPS 3 (DN 80)may be attached by welds that are exempt from size require-ments other than those specified in PW-15.1.

PW-16.5 Internally threaded fittings not exceedingNPS 3 (DN 80) may be attached by a fillet groove weld

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2010 SECTION I

FIG. PW-15 EXAMPLES OF WELD STRENGTH CALCULATIONS

For sketch (a):

(a)

Required weld strength (PG-37.2):

Weld strength

W = (A – A1)Sv

= WL1 in shear + WL2 in shear

= 0.49 (1/2) WL1 (d + 2tn + WL1) Sv fr1 +

0.49 (1/2) WL2 (d + 2tn + WL2) Sv fr1

For sketch (b):

Required weld strength (PG-37.2):

Weld strength

W = (A – A1)Sv

= WL1 in shear + t2 in tension

= 0.49 (1/2) WL1 (d + 2tn + WL1) Sv fr1 +

0.74 (1/2) t2 (d + 2tn) Sv fr1

For sketch (c):

(1) Required weld strength (PG-37.2):

Weld strength

W = (A – A1)Sv

(2) Check nozzle to pad and shell (PG-37.3):

W = (A – A1 – A42 – A5)Sv

= WL2 in shear + t2 in tension

= 0.49 (1/2) WL2 (Dp + WL2) Sv fr3 +

0.74 (1/2) t2 (d + 2tn) Sv fr1

Weld strength = WL1 in shear + t2 in tension

= 0.49 (1/2) WL1 (d + 2tn + WL1) Sv fr1 +

0.74 (1/2) t2 (d + 2tn) Sv fr1

(b)

(c)

WL2

WL1

tn

d

WL1

t2

tn

d

WL1

WL2

t2

tn

d

91



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2010 SECTION I

FIG. PW-16.1 SOME ACCEPTABLE TYPES OF WELDED NOZZLES AND OTHER CONNECTIONS TO SHELLS,DRUMS, AND HEADERS

(a)

(d) (e-1) (e-2) (f)

(k)

Typical Flush Type Nozzles

(h)

tc

tn

t

t1

t2 t2

t2t2

tc

For sketches (d) through (f):

t1 + t2 ≥ 11/4 t min t1 and t2 shall each be not less than the smaller of 1/4 in. (6 mm) or 0.7 t min

tw = 0.7 t min

tw = 0.7 t mintw = 0.7 t min

1/2 t min

1/2 t min

(c)

tc

(b)

Backing strip if used may be removed after welding

tc

tn

t

t1

t

tntn

tn

tn

tc

tn

t

t1t1

t

t

tc

(g)

(l)

tc

tc

Weld to shell

tw = 0.7 t min1/2 t min

tt

(m) (n)

1/2 t min

tc

Weld to pad

92



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2010 SECTION I

FIG. PW-16.1 SOME ACCEPTABLE TYPES OF WELDED NOZZLES AND OTHER CONNECTIONS TO SHELLS,DRUMS, AND HEADERS (CONT’D)

(o)

45 deg max.

30 deg max.

tc

t

tn

t

(q-1)

(q-3)

t1 + t4 ≤ 0.2 t but not greater than 1/4 in. (6 mm)

tn

13

1/2 tmin.

min. of 11/2tt

(q-2)

tn

30 deg min.

1/2 in. (13 mm) min.1/4 in. (6 mm) R min.

t4

tn

t3t

(q-4)

3/4 in. (19 mm) R min.

tn

t

93



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2010 SECTION I


(r)

(s)

(t)

(u-1)

Either method of attachment is satisfactory

(u-2)

(v-1) (v-2)

tn

tc

t2

t1

t

tn

1/2 tmin.

1/4 in. (6 mm)

1/2 tmin.

1/2 tmin.

tw = 0.7 tmin.

tw = 0.7 tmin.

tw = 0.7 tmin.

tw = 0.7 tmin.

t2tc

t1

tc


For sketches (u) and (v):

t1 + t2 ≥ 11/4 tmin.

t1 and t2 shall each be not less than the smaller of 1/4 in. (6 mm) or 0.7 tmin.

For sketches (u-2) and (v-2): For 3 in. (75 mm) pipe and smaller, see exemption in PW-16.4.

t

t

94



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2010 SECTION I


(w-1)


(w-2) (w-3)

(z)

(aa)

(y)

3 in. (DN 80) IPS max.

For sketches (w-2) and (x): For 3 in. (DN 80) pipe and smaller, see exemption in PW-16.4.

tc tn

tc

tc

tn but not less than 1/4 in. (6 mm)

tn but not less than 1/4 in. (6 mm)

1/16 in. (1.5 mm) Recess

Section 1 – 1

tw

tw (see PW-16.5)

tc

t2

t1

tc

1/16 in. (1.5 mm) Recess

tw = 0.7 tmin.

11/4 tmin.

(x)

1/2 tmin.

tn

Do

G

1

1

11/4 tmin.

Do

G

For sketch (aa):

(a) For applications where there are no external loads: G = 1/8 in. (3 mm) max.(b) With external loads: G = 0.005 for Do < 1 in. (25 mm) G = 0.010 for 1 in. < Do < 4 in. (100 mm) G = 0.015 for 4 in. < Do < 65/8 in. (170 mm)

95



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2010 SECTION I


tc

tn

tn min.

1/8 in. (3 mm) min.

(bb)

GENERAL NOTE [illustration (bb)]: NPS 2 (DN 50) max. tn ≤ 1⁄4 in. (6 mm)

FIG. PW-16.2 SOME ACCEPTABLE FORMS OF WELDS FOR LUGS, HANGERS, AND BRACKETS ON SHELLS,DRUMS, AND HEADERS (See PG-55)

0.7 tmin. but not less than1/4 in. (6 mm)

tl

t

(a)


tl

t

(b)


tl

t

(c)

from the outside only as shown in Fig. PW-16.1, illustration(w-3). The groove weld tw shall be not less than the thick-ness of Schedule 160 pipe (ASME B36.10M). The externalfillet weld throat shall be not less than tc.

PW-16.6 Necks and Tubes Up to and IncludingNPS 6 (DN 150) Attached From One Side Only. Necksand tubes not exceeding NPS 6 (DN 150) may be attachedby partial penetration or fillet welds from one side onlyon either the outside or inside of the vessel in accordancewith the provisions given below

(a) When the neck or tube is attached from the outsideonly, a welding groove shall be cut into the surface to adepth of not less than tn on the longitudinal axis of theopening. It is recommended that a recess 1⁄16 in. (1.5 mm)deep be provided at the bottom of the groove in which tocenter the nozzle. The dimension tw of the attachment weldshall be not less than tn nor less than 1⁄4 in. (6 mm). SeeFig. PW-16.1, illustrations (y) and (z).

(b) When the neck or tube is attached from the insideonly, the depth of welding groove or throat of fillet weldshall be at least equal to 11⁄4 tmin. Radial clearance between

96

the vessel hole and nozzle outside diameter at the unweldedside shall not exceed tolerances given in Fig. PW-16.1,illustration (aa). Such attachments shall satisfy the rulesfor reinforcement of opening except that no material in thenozzle neck shall be counted as reinforcement.

(c) Watertubes may be welded into a tubesheet or headerin accordance with the following provisions, where tw, tc,and tmin are as defined in PW-16.2 and illustrated in Fig.PW-16.1, illustration (bb):

(1) The size shall not exceed NPS 2 (DN 50).(2) The thickness shall not exceed 1⁄4 in. (6 mm).(3) The groove depth tw shall be not less than 1⁄8 in.

(3 mm) and tc shall be not less than 1⁄4 in. (6 mm) or 0.7tmin,whichever is smaller.

(4) The tube shall be welded from the waterside ofthe boiler.

(5) The application shall be limited to 650°F (345°C)maximum.

PW-16.7 The minimum throat dimensions of filletwelds defined in PW-16.2 shall be maintained around thecircumference of the attachment, except as provided below:

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2010 SECTION I

(a) For a radial nozzle attachment on a cylindrical shell(or header) as shown in Fig. PW-16.1 where the nozzlemeets the size limitations in PG-32.3.2, the fillet weld legdimensions that meet the minimum throat dimensions shallbe determined at the plane through the longitudinal axisof the cylindrical shell (other planes need not be consid-ered), and these fillet weld leg dimensions shall be usedaround the circumference of the attachment.

(b) For a radial nozzle attachment on a cylindrical shell(or header) as shown in Fig. PW-16.1, illustrations (a)through (c), (g), (h), and (o), where the nozzle exceeds thesize limitations in PG-32.3.2, the fillet weld leg dimensionsthat meet the minimum throat dimensions shall be deter-mined at the plane through the longitudinal axis of thecylindrical shell (other planes need not be considered), andthese fillet weld leg dimensions shall be used around thecircumference of the attachment.

(c) For a radial nozzle attachment on a cylindrical shell(or header) as shown in Fig. PW-16.1, illustrations (a)through (c), (g), and (h), where the outside diameter of thenozzle is the same as the outside diameter of the cylindricalshell or when the outside diameter of the nozzle is toolarge to make a fillet weld, the fillet weld leg dimensionsthat meet the minimum throat dimensions shall be deter-mined at the plane through the longitudinal axis of thecylindrical shell (other planes need not be considered), andthese fillet weld leg dimensions shall be used around thecircumference of the attachment to the maximum extentpossible, and from that point, the fillet weld may be transiti-oned into a butt weld or full-penetration weld, developingthe required strength.

PW-19 WELDED-IN STAYS

Welded-in stays may be used in lieu of threading andshall meet the requirements of PW-19.1 through PW-19.8.

PW-19.1 The stays shall be inserted into countersunkholes through the sheet, except as provided in PW-19.4,and attached by full penetration welds. The area of theweld in shear measured parallel to that portion of the stayextending through the sheet shall be not less than 1.25times the required cross-sectional area of the stay, but inno case shall the size of the weld be less than 3⁄8 in. (10 mm).

PW-19.2 The ends of the stays shall not be coveredby weld metal and the face of the welds shall not be belowthe outside surface of the plates.

PW-19.3 The ends of stays inserted through the sheetshall not project more than 3⁄8 in. (10 mm) beyond surfacesexposed to products of combustion.

PW-19.4 Diagonal stays shall be attached to the innersurface of the shell, but not the head, by fillet welds only.See Figs. PW-19.4(a) and PW-19.4(b), provided

97

PW-19.4.1 Fillet welds shall be not less than 3⁄8 in.(10 mm) size and shall continue the full length of eachside of the portion of the stay in contact with the shell.The product of the aggregate length of these fillet weldstimes their throat shall be not less than 1.25 times therequired cross-sectional area of the stay. A fillet weld acrossthe end of the stay is optional but shall not be credited incalculating the required area of fillet welds.

PW-19.4.3 The longitudinal center line of the stay,projected if necessary, shall intersect the inner surface ofthe plate to which the stay is attached within the outerboundaries of the attaching welds, also projected if nec-essary.

PW-19.5 The pitch of stays attached by welding to flatsurfaces shall comply with the requirements of PFT-27.

PW-19.6 The welding shall be done in such a mannerthat excessive weld deposits do not project through thesurface of the plate at the root of the weld.

PW-19.7 The welding shall be postweld heat treatedin accordance with PW-39.

PW-19.8 Telltale holes are not required in stayboltsattached by welding.

FABRICATION

PW-26 GENERAL

The rules in the following paragraphs apply specificallyto the fabrication of boilers and parts thereof that are fabri-cated by welding and shall be used in conjunction withthe general requirements for fabrication in Part PG, as wellas with the specific requirements for fabrication in theapplicable Parts of this Section that pertain to the type ofboiler under consideration.

PW-27 WELDING PROCESSES

The welding processes that may be used under this Partshall meet all the test requirements of Section IX and arerestricted to PW-27.1 through PW-27.4.

PW-27.1 The following welding processes may be usedfor any Section I construction: shielded metal arc, sub-merged arc, gas metal arc, flux cored arc, gas tungsten arc,plasma arc, atomic hydrogen arc, oxyhydrogen, oxyacety-lene, laser beam, electron beam, flash, induction, pressurethermit, pressure gas, and inertia and continuous drivefriction welding.

Resistance welding is permitted within the thickness anddiameter limitations given in PG-9.5, except that circumfer-ential butt welds and pressure-bearing attachment welds arenot restricted. Resistance welding of nonpressure-bearing



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2010 SECTION I

FIG. PW-19.4(a) SOME ACCEPTABLE TYPES OF DIAGONAL BRACES FOR INSTALLATION BY WELDING

GENERAL NOTE: A round bar or a round bar with a forged palm

FIG. PW-19.4(b) UNACCEPTABLE TYPES OF DIAGONAL BRACES FOR INSTALLATION BY WELDING

attachments is not restricted, except as provided in PW-27.2.

PW-27.2 Arc stud welding and resistance stud weldingmay be used for nonpressure-bearing attachments havinga load- or nonload-carrying function. Stud size shall belimited to 1 in. (25 mm) diameter maximum for roundstuds or an equivalent cross-sectional area for studs withother shapes. For load-carrying attachments, the require-ments of PW-28.6 shall be met prior to the start of produc-tion welding, and the postweld heat treatment requirementsof PW-39 shall also be complied with.

PW-27.3 The electroslag welding process may be usedfor butt welds only in austenitic stainless steels of typeslisted in PW-5.3 and ferritic steels. Electroslag welds inferritic steels require special NDE [Table PW-11, GeneralNotes (a) and (b)] and special heat treatment (PW-39.7).

PW-27.4 Definitions are given in Section IX, whichinclude variations of these processes.

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PW-27.5 When welding UNS N06230 with filler metalof the same nominal composition as the base metal, onlyGMAW or GTAW processes are allowed.

PW-28 WELDING QUALIFICATIONAND WELD RECORDS

PW-28.1 Requirements for Qualification of WeldingProcedures, Welders, and Welding Operators

PW-28.1.1 The Welding Procedure Specifications,the welders, and the welding operators used in weldingpressure parts and in joining load-carrying nonpressureparts, such as all permanent or temporary clips and lugs,to pressure parts shall be qualified in accordance withSection IX.

PW-28.1.2 Except as provided in PW-28.1.2(a) and(b), the Welding Procedure Specification, the welders andthe welding operators used in welding nonpressure-bearing



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attachments which have essentially no load-carrying func-tion (such as extended heat transfer surfaces, insulationsupport pins, etc.) to pressure parts shall be qualified inaccordance with Section IX.

(a) When the welding process is automatic, weldingprocedure and performance qualification testing is notrequired.

(b) When the material used for the nonpressure partmakes the mechanical test requirements for procedure qual-ification and performance qualifications impracticable (i.e.,insufficient material ductility), a weld test coupon may beevaluated using the macro-examination method for bothgroove and fillet welds. The test coupon may be of produc-tion configuration and shall be of sufficient length to con-tain a specimen for macro-examination. Heat treatmentshall be considered a nonessential variable. The weldablequality of the nonpressure part materials shall be verifiedby the macro-examination of a single cross-section of theweld. Visual examination of the weld metal and heat-affected zone of both the pressure part and nonpressurepart material shall show complete fusion and freedom fromcracks.

PW-28.1.3 Welding of all test coupons shall be con-ducted by the Manufacturer. Testing of all test couponsshall be the responsibility of the Manufacturer. Qualifica-tion of a welding procedure, a welder, or a welding operatorby one Manufacturer shall not qualify that procedure,welder, or the welding operator for any other Manufacturerexcept as provided in QW-201 and QW-300 of Section IXand PW-28.5.

PW-28.2 No production work shall be undertaken untilthe procedures, the welders, and the welding operatorshave been qualified, except that performance qualificationby radiography, in conformance with Section IX, QW-304for welders or QW-305 for welding operators, may beperformed within the first 3 ft (1 m) of the first produc-tion weld.

PW-28.4 The Manufacturer shall maintain qualifica-tion records of the welding procedures, welders, and weld-ing operators employed, showing the date, results of thetests, and the identification mark assigned to each welder.These records shall be certified by the Manufacturer bysignature or some other method of control in accordancewith the Manufacturer’s Quality Control System and beaccessible to the Authorized Inspector.

PW-28.4.1 The Manufacturer shall also establish aprocedure whereby all welded joints, except as permittedin PW-28.4.2 and PW-28.4.3, can be identified as to thewelder or welding operator who made them. This procedureshall use one or more of the following methods and beacceptable to the Authorized Inspector. The welder orwelding operator may stamp his identification mark on oradjacent to all welded joints made by him, or he may stamp

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on or adjacent to a continuous weld or a series of similarjoints made by him at intervals of not greater than 3 ft(1 m), or, in lieu of stamping, the Manufacturer may keepa record of welded joints and the welders or welding opera-tors used in making the joints.

PW-28.4.2 When making multiple load-carrying ornonload-carrying structural attachment welds on pressureparts, the Manufacturer need not identify the welder orwelding operator that welded each individual joint, pro-vided

(a) the Manufacturer’s Quality Control System includesa procedure whereby the identity of the welders or weldingoperators that made such welds on each pressure part willbe maintained so that the Inspector can verify that thewelders or welding operators were all properly qualified

(b) the welds are all the same type and configuration andare welded with the same welding procedure specification

PW-28.4.3 Identification of welders or welding oper-ators making tack welds that become part of a final pres-sure-retaining weld or structural attachment weld is notrequired provided the Quality Control System of the Manu-facturer includes a procedure to permit the Inspector toverify that such tack welds were made by qualified weldersor welding operators.

PW-28.5 DELETED

PW-28.6 In the case where stud welding is used toattach load-carrying studs, a production stud weld test ofthe procedure and welding operator shall be performed ona separate test plate or tube prior to the start of productionwelding on the first work piece. This weld test shall consistof five studs, welded and subjected to either the bend ortorque stud weld testing described in Section IX.

PW-28.7 If tube butt welds are made using the flashwelding process, production testing shall be performed inaccordance with Section IX, QW-199.1.3 as follows:

(a) one sample shall be tested at the start of production(b) one sample shall be tested at the beginning, mid-

point, and end of each work shift(c) when production shifts are consecutive, a test at the

end of the shift may serve as the test for the beginning ofthe next shift

(d) when a welding operator is replaced during pro-duction

(e) if any machine settings are changedWhen any production run weld fails to pass the required

tests, the welding parameters shall be adjusted until twoconsecutive welds pass the bend test. In addition, all weldsthat were made subsequent to the previous successful test

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shall be either cut out and rewelded or cut out and testedin reverse sequence of welding until two successive weldspass the tests.

PW-29 BASE METAL PREPARATION

PW-29.1 The preparation of joints prior to weldingmay involve any of the conventional methods in use suchas machining, thermal cutting, chipping, grinding, or com-binations of these.

PW-29.2 Where thermal cutting is used, the effect onthe mechanical and metallurgical properties of the basemetal shall be taken into consideration.

PW-29.3 The method of base metal preparation usedshall leave the welding groove with reasonably smoothsurfaces and free from deep notches, striations, or irregular-ities. The surfaces for welding shall be free of all scale,rust, oil, grease, or other foreign materials.

PW-29.4 Cast surfaces to be welded shall be machined,chipped, or ground where necessary to remove foundryscale and to expose sound metal.

PW-31 ASSEMBLY

PW-31.1 Parts that are being welded shall be fitted,aligned, and retained in position during the welding opera-tion within the tolerance specified in PW-33.

PW-31.2 Bars, jacks, clamps, tack welds, or otherappropriate means may be used to hold the edges of theparts to be welded in alignment.

PW-31.3 Tack welds used to secure alignment shalleither be removed completely when they have served theirpurpose or their stopping and starting ends shall be properlyprepared by grinding or other suitable means so that theymay be satisfactorily incorporated into the final weld. Tackwelds, whether removed or left in place, shall be madeusing a fillet weld or butt weld procedure qualified inaccordance with Section IX. Tack welds to be left in placeshall be made by welders qualified in accordance withSection IX and shall be examined visually for defects and,if found to be defective, shall be removed.

PW-31.4 When joining two parts by the inertia andcontinuous drive friction welding processes, one of the twoparts must be held in a fixed position and the other partrotated. The two faces to be joined must be essentiallysymmetrical with respect to the axis of rotation. Some ofthe basic types of applicable joints are solid round-to-solidround, tube-to-tube, solid round-to-tube, solid round-to-plate, and tube-to-plate.

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TABLE PW-33ALIGNMENT TOLERANCE OF SECTIONS

TO BE BUTT WELDED

Direction of Joints inCylindrical Shells

Section Longitudinal CircumferentialThickness, in. (mm) in. (mm) in. (mm)

Up to 1⁄2 (13), incl. 1⁄4t1⁄4t

Over 1⁄2 (13) to 3⁄4 (19), incl. 1⁄8 (3.0) 1⁄4tOver 3⁄4 (19) to 11⁄2 (38), incl. 1⁄8 (3.0) 3⁄16 (5)Over 11⁄2 (38) to 2 (50), incl. 1⁄8 (3.0) 1⁄8tOver 2 (50) Lesser of 1⁄16t Lesser of 1⁄8t or

or 3⁄8 (10) 3⁄4 (19)

PW-33 ALIGNMENT TOLERANCE, SHELLSAND VESSELS (INCLUDING PIPE ORTUBE USED AS A SHELL)

PW-33.1 Alignment of sections at edges to be buttwelded shall be such that the maximum offset is not greaterthan the applicable amount as listed in Table PW-33, wheret is the nominal thickness of the thinner section at the joint.

PW-33.2 Joints in spherical vessels and within headsand joints between cylindrical shells and hemisphericalheads shall meet the requirements in PW-33.1 above forlongitudinal joints in cylindrical shells.

PW-33.3 Any offset within the allowable toleranceprovided above shall be faired at a 3 to 1 taper over thewidth of the finished weld, or if necessary, by addingadditional weld metal beyond what would otherwise bethe edge of the weld.

PW-34 ALIGNMENT, TUBE AND PIPE

PW-34.1 When tubes or pipes are welded together, thealignment shall be such that the inside surfaces providefor complete weld penetration. The weld shall meet thereinforcement requirements of PW-35.

PW-35 FINISHED LONGITUDINAL ANDCIRCUMFERENTIAL JOINTS

PW-35.1 Butt welds shall have complete joint penetra-tion. To assure that the weld grooves are completely filledso that the surface of the weld metal at any point is notbelow the surface of the adjoining base materials, weldmetal may be added as reinforcement on each face of theweld. The thickness of the weld reinforcement on eachface shall not exceed the following:

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2010 SECTION I

Maximum Reinforcement,in. (mm)

CircumferentialJoints in Pipe Other

Nominal Thickness, in. (mm) and Tubing Welds

Up to 1⁄8 (3) 3⁄32 (2.5) 3⁄32 (2.5)Over 1⁄8 (3) to 3⁄16 (5), incl. 1⁄8 (3.0) 3⁄32 (2.5)Over 3⁄16 (5) to 1⁄2 (13), incl. 5⁄32 (4.0) 3⁄32 (2.5)Over 1⁄2 (13) to 1 (25), incl. 3⁄16 (5.0) 3⁄32 (2.5)Over 1 (25) to 2 (50), incl. 1⁄4 (6.0) 1⁄8 (3.0)Over 2 (50) to 3 (75), incl. [Note (1)] 5⁄32 (4.0)Over 3 (75) to 4 (100), incl. [Note (1)] 7⁄32 (5.5)Over 4 (100) to 5 (125), incl. [Note (1)] 1⁄4 (6.0)Over 5 (125) [Note (1)] 5⁄16 (8.0)

NOTE:(1) The greater of 1⁄4 in. (6 mm) or 1⁄8 times the width of the weld in

inches (mm).

As-welded surfaces are permitted; however, the surface ofthe welds shall be sufficiently free from coarse ripples,grooves, overlaps, abrupt ridges, and valleys to avoid stressraisers. Undercuts shall not exceed 1⁄32 in. (0.8 mm) or 10%of the wall thickness, whichever is less, and shall notencroach on the required section thickness. The surfacesof the finished weld shall be suitable to permit properinterpretation of the nondestructive examinations. If thereis a question regarding the surface condition of the weldwhen interpreting radiographic film, the film shall be com-pared to the actual weld surface for determination of accept-ability.

PW-35.2 The weld reinforcement need not be removedexcept to the extent necessary to meet the thickness require-ments in PW-35.1.

PW-35.3 Backing strips used at longitudinal weldedjoints shall be removed and the weld surface prepared forvolumetric examination as required. Inside backing ringsmay remain at circumferential joints of cylinders, providedthey meet the requirements of PW-41.

PW-35.4 The welded joint between two membersjoined by the inertia and continuous drive friction weldingprocesses shall be full penetration weld. Visual examina-tion of the as-welded flash roll of each weld shall be madeas an in-process check. The weld upset shall meet thespecified amount with ±10%. The flash shall be removedto sound metal.

PW-36 MISCELLANEOUS WELDINGREQUIREMENTS

PW-36.1 Before applying weld metal on the secondside to be welded, the root of double-welded butt jointsshall be prepared by suitable methods such as chipping,grinding, or thermal gouging, so as to secure sound metalat the base of weld metal deposited on the face side, except

101

for those processes of welding by which proper fusion andpenetration are otherwise obtained and by which the rootof the weld remains free from impurities.

PW-36.2 Fillet Welds. In making fillet welds, the weldmetal shall be deposited in such a way as to secure adequatepenetration into the base metal at the root of the weld.Undercuts on pressure-retaining boundaries shall notexceed the lesser of 1⁄32 in. (0.8 mm) or 10% of the nominalthickness of the adjoining surface and shall not encroachupon the required section thickness. The surface of thewelds shall be free from coarse ripples or grooves, andshall merge smoothly with the surfaces being joined. Con-cavity of the face of the weld is permissible, provided itdoes not encroach on the required weld thickness.

PW-38 PREHEATINGPW-38.1 The need for and the temperature of preheat

are dependent upon a number of factors such as chemicalanalysis, degree of restraint of the parts being joined, ele-vated temperature mechanical properties, and materialthicknesses. Some practices used for preheating aredescribed in A-100 as a general guide for the materialslisted by P-Numbers of Section IX. It is cautioned that thepreheating suggested in A-100 does not necessarily ensuresatisfactory completion of the welded joint and that therequirements for individual materials within the P-Numberlisting may have preheating more or less restrictive thanthis general guide. The welding procedure specificationfor the material being welded shall specify the minimumpreheating requirements described in the welding proce-dure qualification requirements of Section IX.

PW-38.2 Preheat for welding or thermal cutting maybe applied by any method that does not harm the basematerial or any weld metal already applied, or that doesnot introduce into the welding area foreign material thatis harmful to the weld.

PW-39 REQUIREMENTS FOR POSTWELDHEAT TREATMENT

The rules in the following paragraphs apply specificallyto the fabrication of the boiler proper and parts thereofand do not apply to the external piping as defined in thePreamble.

PW-39.1 Before applying the detailed requirementsand exemptions in these paragraphs, satisfactory weld pro-cedure qualifications of the procedures to be used shall beperformed in accordance with all the essential variables ofSection IX including conditions of postweld heat treatmentor lack of postweld heat treatment and including otherrestrictions listed below. Except as otherwise specificallyprovided in PFT-29, PMB-9, PW-39.8, PW-40.2, PW-40.3,

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and in the notes within Table PW-39, all welded pressureparts of power boilers shall be given a postweld heat treat-ment at a temperature not less than that specified in TablePW-39. The materials in Table PW-39 are listed in accor-dance with the materials P-Number grouping of QW-420of Section IX.

PW-39.2 When pressure parts of two different P-Num-ber groups are joined by welding, the postweld heat treat-ment shall be that specified in Table PW-39 and applicablenotes for the material requiring the higher postweld heattreatment temperature, except as noted in PW-39.2.1. Whennonpressure parts are welded to pressure parts, the postweldheat treatment temperature of the pressure parts shallcontrol.

Pressure part welds and attachment welds using ferriticfiller metals that have a specified chromium content ofmore than 3% shall receive a postweld heat treatment. Thepostweld heat treatment time and temperature used shallbe not less than that shown in Table PW-39 for a basemetal of equivalent analysis.

PW-39.2.1 Fillet welds, partial penetration welds,and full penetration welds through the tube or pipe thick-ness, attaching P-No. 5A tubes and pipe to headers of lowerP-Number material, may be postweld heat treated at thetemperature specified in Table PW-39 for the lower P-Number material provided the tubes or pipe comply withall the following conditions:

(a) a maximum specified chromium content of 3.0%(b) a maximum size of NPS 4 (DN 100)(c) a maximum thickness of 1⁄2 in. (13 mm)(d) a maximum specified carbon content of not more

than 0.15%

PW-39.3 In the procedures that follow, the volume ofmetal required to be heated, to meet or exceed the minimumpost weld heat treatment temperatures listed in Table PW-39, is defined as the soak band. As a minimum, the soakband shall contain the weld and a portion of the base metalon each side of the weld being heat treated, including theweld heat affected zones. The width of each portion ofbase metal to be included in the soak band shall be equalto the lesser of the vessel or shell thickness, or 2 in.(50 mm). A greater amount of base material, on eitheror both sides of the weld, may also be heated to permittemperature gradient control.

The weldment shall be heated slowly to the temperaturespecified in Table PW-39 and held for the specified time,and shall be allowed to cool slowly in a still atmosphereto a temperature not exceeding 800°F (425°C). Severalweldments of varied thickness may be postweld heattreated in the same furnace at the same time.

The term nominal thickness in Table PW-39 is the thick-ness of the weld, pressure retaining material, or the thinnerof the sections being joined, whichever is least. For fillet

102

welds, the nominal thickness is the throat thickness, and forpartial penetration and material repair welds, the nominalthickness is the depth of the weld groove or preparation.For combination groove and fillet welds, nominal thicknessis the total combined thickness of the deposited weld,groove depth plus fillet weld throat. The total depth of aweld repair shall be taken as the sum of the depths forrepairs made from both sides of a weld at a given location.

The holding time at temperature as specified in TablePW-39 need not be continuous. It may be an accumulationof time of multiple postweld heat treat cycles.

PW-39.4 The weldments shall be postweld heat treatedby any of the following methods.

PW-39.4.1 Heating the complete assembly as a unit.

PW-39.4.2 Heating sections of assemblies.

PW-39.4.3 In cases where the vessel is postweldheat treated in sections, the heat treatment of the final jointsmay be performed by one of the following methods.

PW-39.4.3.1 By uniformly heating a circumferen-tial band around the vessel, to the temperature and for thetime specified in Table PW-39 for postweld heat treatment.

PW-39.4.3.2 Alternatively, the post weld heattreatment of the final joints may be performed by heatingin the furnace, provided the overlap of the heated sectionsof the vessel is at least 5 ft (1.5 m). When this procedureis used, the portion outside of the furnace shall be thermallyshielded (using blankets, brick, etc.) so that the temperaturegradient is not harmful.

PW-39.4.3.2.1 Where the cross section of thevessel that projects from the furnace contains a nozzle,consideration shall be given to controlling the temperaturein the nozzle, so that the temperature gradient is notharmful.

PW-39.5 Nozzles or other welded attachments forwhich postweld heat treatment is required may be locallypostweld heat treated by one of the following methods.

PW-39.5.1 By heating a circumferential band aroundthe entire vessel with the welded connection located at themiddle of the band. Except as modified below, the soakband shall extend around the entire vessel, and shall includethe nozzle of welded attachment.

PW-39.5.1.1 By heating a circumferential bandaround the entire vessel with the welded connection locatedat the middle of the band. Provided the required soak bandaround the nozzle or attachment weld, as defined in PW-39.3, is heated to the required temperature and held forthe required time, as specified in Table PW-39, the remain-der of the circumferentially-heated band may be varied inwidth around the circumference of the vessel. The tempera-ture within the heated band shall be controlled to preventharmful gradients.



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TABLE PW-39MANDATORY REQUIREMENTS FOR POSTWELD HEAT TREATMENT OF PRESSURE PARTS AND ATTACHMENTS

Minimum Holding Time at Normal Temperature for Weld Thickness (Nominal)Minimum HoldingTemperature, °F Up to 2 in. Over 2 in. (50 mm) to 5 Over 5 in.

Material (°C) (50 mm) in. (125 mm) (125 mm)

P-No. 1 1,100 (595) 1 hr/in. (1 hr/25 mm), 2 hr plus 15 min for each 2 hr plus 15 min forGroup No. 1,2,3 15 min minimum additional inch (25 mm) each additional

over 2 in. (50 mm) inch (25 mm) over2 in. (50 mm)

GENERAL NOTES:(a) Postweld heat treatment is not mandatory for P-No. 1 materials under the following conditions:

(1) when the nominal thickness of a groove weld or combination groove and fillet weld does not exceed 3⁄4 in. (19 mm), and a minimumpreheat of 200°F (95°C) is applied when the nominal material thickness of any of the base metals in the weld joint exceeds 1 in. (25 mm).

(2) when the nominal thickness of a groove weld, or combination groove and fillet weld is greater than 3⁄4 in. (19 mm) but does not exceed11⁄2 in. (38 mm), and:

(a) the calculated carbon equivalent, CE, of any of the base metals in the weld joint is less than or equal to 0.45, using the formulaCE p C + (Mn + Si)/6 + (Cr + Mo + V)/5 + (Ni + Cu)/15

Note: The maximum chemical composition limit from the material specification or the actual values from a chemical analysis or materialtest report shall be used in computing CE. If the chemistry values required for the last two terms are not available, 0.15% shall be substitutedfor those two terms as follows:

CE p C + (Mn + Si)/6 + 0.15(b) a minimum preheat of 250°F (120°C) is applied(c) no individual weld pass thickness exceeds 1⁄4 in. (6 mm)

(3) for fillet welds used on slip-on and socket welding flanges and fittings conforming to the rules of PW-41, when the following conditionsare met:(a) a fillet weld throat thickness of 1⁄2 in. (13 mm) or less, regardless of base metal thickness(b) a minimum preheat of 200°F (95°C) when the thickness of a pressure part at the weld exceeds 3⁄4 in. (19 mm)

(4) for fillet welds attaching nonpressure parts to pressure parts that have a throat thickness of 1⁄2 in. (13 mm) or less, provided preheat toa minimum temperature of 200°F (95°C) is applied when the thickness of the pressure part exceeds 3⁄4 in. (19 mm)

(5) for welds used to attach extended heat absorbing surface to tubes and insulation attachment pins to pressure parts(6) for tubes or pressure retaining handhole and inspection plugs or fittings that are secured by physical means (rolling, shoulder construction,

machine threads, etc.) and seal welded, provided the seal weld has a throat thickness of 3⁄8 in. (10 mm) or less, and preheat to a minimumtemperature of 200°F (95°C) is applied when the thickness of either part exceeds 3⁄4 in. (19 mm)

(7) for studs welded to pressure parts for purposes not included in (4) above, provided preheat to a minimum temperature of 200°F (95°C)is applied when the thickness of the pressure part exceeds 3⁄4 in. (19 mm)

(8) for tube-to-tubesheet welded attachment of P-No. 1, Group Nos. 1 and 2 material in firetube boilers in accordance with Fig. PFT-12.1sketches (f) and (g), if the depth of the weld groove or preparation does not exceed 3⁄8 in. (10 mm), provided a minimum preheat of200°F (95°C) is applied when the tubesheet thickness exceeds 3⁄4 in. (19 mm)

(9) for fillet welds attaching connections to a vessel, provided that all of the following conditions are met:(a) the diameter of the finished opening (diameter d in Figs. PG-33.1, PG-33.2, and PW-15) does not exceed that allowed in PG-32.1.2

or 2 in. (50 mm), whichever is less(b) the throat thickness does not exceed 3⁄8 in. (10 mm)(c) preheat to a minimum temperature of 200°F (95°C) is applied when the thickness of either part exceeds 3⁄4 in. (19 mm)(d) the connections are not placed in the vessel such as to form ligaments, the efficiency of which would affect the vessel thickness

(10) for combination groove and fillet welds attaching nonpressure parts to pressure parts, with a weld thickness of 1⁄2 in. (13 mm) or less,provided preheat to a minimum of 200°F (95°C) is applied when the thickness of the pressure part exceeds 3⁄4 in. (19 mm)

(11) for corrosion-resistant weld metal overlay cladding of pipe or tube materials, provided that all of the following conditions are met:(a) the thickness of the overlay cladding is 1⁄4 in. (6 mm) or less(b) preheat to a minimum temperature of 200°F (95°C) is applied when the thickness of the pressure part exceeds 3⁄4 in. (19 mm)(c) the pipe or tube material

(1) does not exceed NPS 5 (DN 125) outside diameter(2) is not used as a drum or shell

(12) for combination groove and fillet welds attaching connections to a vessel as depicted in Fig. PW-16.1(z), provided all of the followingconditions are met:

(a) both the tube and vessel are P-No. 1, Group No. 1 or 2 material(b) the diameter of the finished opening does not exceed that allowed in PG-32.1.2 or 2 in. (50 mm), whichever is less(c) the nominal thickness of the weld does not exceed 3⁄8 in. (10 mm)(d) the connections are not placed in the vessel such as to form ligaments, the efficiency of which would affect the vessel thickness(e) a minimum preheat of 200°F (95°C) is applied when the thickness of either part exceeds 3⁄4 in. (19 mm)

(13) for butt welds and corner joints in fireboxes and waterlegs meeting the requirements of PFT-21, with or without the addition of filletwelds, when the nominal thickness does not exceed 3⁄4 in. (19 mm)

(14) for welds attaching nonload-carrying studs not exceeding 1⁄2 in. (13 mm) in diameter when using an automatic arc stud welding orautomatic resistance stud welding process

(15) for attaching bare wire thermocouples by capacitor discharge welding or electric resistance welding, provided the following requirementsare met:

(a) the requirements of PW-39.8(b) the minimum wall thickness shall be 0.200 in. (5.0 mm) or greater

(b) When it is impractical to postweld heat treat at the temperature specified in this Table, it is permissible to carry out the postweld heat treatmentat lower temperatures for longer periods of time in accordance with Table PW-39.1.

(c) For all P-No. 1 Group No. 1 materials, and for P-No. 1 Group No. 2 materials having a maximum actual carbon content of 0.30%, thepostweld heat treatment requirement of PWT 11.2 for tubes welded to tubular manifolds or headers is not mandatory when all of the followingconditions are met:(1) the tubes do not exceed 2 in. (50 mm) O.D.(2) the header does not exceed NPS 8 (DN 200)(3) the header thickness does not exceed 1⁄2 in. (13 mm)(4) a minimum preheat of 200°F (95°C) is applied

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2010 SECTION I

TABLE PW-39MANDATORY REQUIREMENTS FOR POSTWELD HEAT TREATMENT

OF PRESSURE PARTS AND ATTACHMENTS (CONT’D)

Minimum Holding Time at Normal Temperaturefor Weld Thickness (Nominal)Minimum Holding

Temperature, °F Up to 2 in. Over 2 in. (50 mm) to 5 Over 5 in.Material (°C) (50 mm) in. (125 mm) (125 mm)

P-No. 3 1,100 (595) 1 hr/in. (1 hr/25 mm), 2 hr plus 15 min for each 2 hr plus 15 min forGroup No. 1,2,3 15 min minimum additional inch (25 mm) each additional

over 2 in. (50 mm) inch (25 mm) over2 in. (50 mm)

GENERAL NOTES:(a) Except for P-No. 3 Group No. 3, postweld heat treatment of P-No. 3 materials is not mandatory under the following conditions (postweld

heat treatment is mandatory for P-No. 3 Group No. 3 materials for all thicknesses):(1) for circumferential butt welds in pressure parts with both a nominal wall thickness of 5⁄8 in. (16 mm) or less, and a specified maximum

carbon content (SA material specification carbon content, except when further limited by the Purchaser to a value within the specificationlimits) of not more than 0.25%

(2) for fillet welds used on socket welding fittings conforming to the rules of PW-41, when the following conditions are met:(a) a fillet weld throat thickness of 1⁄2 in. (13 mm) or less, regardless of base metal thickness(b) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.25%(c) a minimum preheat of 200°F (95°C) when the thickness of a pressure part at the weld exceeds 5⁄8 in. (16 mm)

(3) for fillet welds with a throat thickness of 1⁄2 in. (13 mm) or less and combination groove and fillet welds with a weld thickness of 1⁄2 in.(13 mm) or less attaching nonpressure parts having a specified maximum carbon content (SA material specification carbon content,except when further limited by the Purchaser to a value within the specification limits) of not more than 0.25% provided preheat to aminimum temperature of 200°F (95°C) is applied when the pressure part exceeds 5⁄8 in. (16 mm)

(4) for welds used to attach extended heat-absorbing surface to tubes and insulation attachment pins to pressure parts(5) for tubes or pressure retaining handhole and inspection plugs or fittings that are secured by physical means (rolling, shoulder construction,


(6) postweld heat treatment is not mandatory for studs welded to pressure parts for purposes not included in (4) above and which have aspecified maximum carbon content of not more than 0.25% (SA material specification carbon content, except when further limited byPurchaser to a value within the specification limits), provided a preheat to a minimum temperature of 200°F (95°C) is applied whenthe thickness of the pressure part exceeds 5⁄8 in. (16 mm)

(7) for fillet welds attaching connections to a vessel, provided that all of the following conditions are met:(a) the diameter of the finished opening (diameter d in Figs. PG-33.1, PG-33.2, and PW-15) does not exceed that allowed in PG-32.1.2

or 2 in. (50 mm), whichever is less(b) the throat thickness does not exceed 3⁄8 in. (10 mm)(c) preheat to a minimum temperature of 200°F (95°C) is applied when the thickness of either part exceeds 5⁄8 in. (16 mm)(d) the connections are not placed in the vessel such as to form ligaments, the efficiency of which would affect the vessel thickness(e) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.25%(8) for corrosion-resistant weld metal overlay cladding of pipe or tube materials, provided that all of the following conditions are met:

(a) the thickness of the overlay cladding is 1⁄4 in. (6 mm) or less(b) preheat to a minimum temperature of 200°F (95°C) is applied when the thickness of the pressure part exceeds 5⁄8 in. (16 mm)(c) the pipe or tube material


(9) for welds attaching nonload-carrying studs not exceeding 1⁄2 in. (13 mm) in diameter when using an automatic arc stud welding orautomatic resistance stud welding process

(10) for attaching bare wire thermocouples by capacitor discharge welding or electric resistance welding, provided the following requirementsare met:

(a) the requirements of PW-39.8(b) the minimum wall thickness shall be 0.200 (5.0 mm) or greater

(b) When it is impractical to postweld heat treat at the temperature specified in this table, it is permissible to carry out the postweld heat treatmentat lower temperatures for longer periods of time in accordance with Table PW-39.1.

(c) General Note (a) does not apply to welds using the inertia and continuous drive friction welding processes. Postweld heat treatment is mandatoryfor all thicknesses of materials welded using inertia and continuous drive friction welding.

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Minimum Holding Time at Normal Temperature for Weld Thickness (Nominal)Minimum HoldingTemperature, °F Up to 2 in. Over 2 in. (50 mm) to Over 5 in.

Material (°C) (50 mm) 5 in. (125 mm) (125 mm)

P-No. 4 1,200 (650) 1 hr/in. (1 hr/25 mm), 1 hr/in. (1 hr/25 mm) 5 hr plus 15 min forGroup No. 1,2 15 min minimum each additional

inch (25 mm) over5 in. (125 mm)


(1) for circumferential butt welds in pressure parts with all the following conditions:(a) a nominal base metal thickness of 5⁄8 in. (16 mm) or less at the weld(b) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.15%(c) a minimum preheat of 250°F (120°C). This minimum preheat is not required for SA-213 Grade T11 tube materials with a maximum

outside diameter of 1.5 in. (38 mm) and a maximum thickness of 0.165 in. (4.2 mm) when buttwelded using a multipass GTAWprocess

(2) for fillet welds used on socket welding fittings conforming to the rules of PW-41, when the following conditions are met:(a) a fillet weld throat thickness of 1⁄2 in. (13 mm) or less, regardless of base metal thickness(b) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.15%(c) a minimum preheat of 250°F (120°C)

(3) for pipe and tube materials meeting the requirements of (1)(a) and (1)(b) above and having fillet welds attaching nonpressure parts tothem, provided the fillet weld has a throat thickness of 1⁄2 in. (13 mm) or less and the material is preheated to 250°F (120°C) minimum;or combination groove and fillet welds attaching nonpressure parts to pressure parts, with a weld thickness of 1⁄2 in. (13 mm) or less,provided the material is preheated to a minimum of 250°F (120°C); or heat-absorbing surfaces and non-load-carrying studs attached tothem, provided the material is preheated to 250°F (120°C) minimum. A lower preheating temperature may be used, provided specificallycontrolled procedures necessary to produce sound joints are used. Such procedures shall include but shall not be limited to the following:(a) the throat thickness of fillet welds shall be 1⁄2 in. (13 mm) or less(b) the maximum continuous length of fillet welds shall be not over 4 in. (100 mm)(c) electrodes or filler metal shall be dry and shall provide a low-hydrogen weld deposit. Chromium-molybdenum filler metals shall have

a maximum specified chromium content of not more than 2.50% and a maximum specified carbon content of not more than 0.05%(d) the thickness of the test plate used in making the welding procedure qualification of Section IX shall not be less than that of the

material to be welded(4) for tubes or pressure retaining handhole and inspection plugs or fittings that are secured by physical means (rolling, shoulder construction,


(5) for corrosion-resistant weld metal overlay cladding of pipe or tube materials, provided that all of the following conditions are met:(a) the thickness of the overlay cladding is 1⁄4 in. (6 mm) or less(b) preheat to a minimum temperature of 250°F (120°C) is applied when the thickness of the pressure part exceeds 1⁄2 in. (13 mm)(c) the pipe or tube material


(6) for electric resistance welds used to attach extended heat-absorbing fins to pipe and tube materials, provided the following requirementsare met:(a) a maximum pipe or tube size of NPS 4 (DN 100)(b) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within specification limits) of not more than 0.15%.(c) a maximum fin thickness of 1⁄8 in. (3 mm)(d) prior to using the welding procedure, the Manufacturer shall demonstrate that the heat-affected zone does not encroach upon the

minimum wall thickness(7) for welds attaching nonload-carrying studs or insulation attachment pins not exceeding 1⁄2 in. (13 mm) in diameter when using an automatic

arc stud welding or automatic resistance stud welding process(8) postweld heat treatment is not mandatory for attaching bare wire thermocouples by capacitor discharge welding or electric resistance

welding, provided the following requirements are met:(a) The requirements of PW-39.8.(b) The maximum carbon content of the base material is restricted to 0.15%.(c) The minimum wall thickness shall be 0.20 in. (5.0 mm) or greater.

(b) General Note (a) does not apply to welds using the inertia and continuous drive friction welding processes. Postweld heat treatment is mandatoryfor all thicknesses of materials welded using inertia and continuous drive friction welding.

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P-No. 5A 1,250 (675) 1 hr/in. (1 hr/25 mm), 1 hr/in. (1 hr/25 mm) 5 hr plus 15 min forGroup No. 1 15 min minimum each additionaland P-No. 5B inch (25 mm) overGroup No. 1 5 in. (125 mm)

GENERAL NOTES:(a) Postweld heat treatment is not mandatory under the following conditions:

(1) for circumferential butt welds in pressure parts with all of the following conditions:(a) a maximum specified chromium content of 3.0%(b) a nominal base metal thickness of 5⁄8 in. (16 mm) or less at the weld(c) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.15%(d) a minimum preheat of 300°F (150°C)

(2) for fillet welds used on socket welding fittings conforming to the rules of PW-41, when the following conditions are met:(a) a maximum specified chromium content of 3.0%(b) a fillet weld throat thickness of 1⁄2 in. (13 mm) or less, regardless of base metal thickness(c) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.15%(d) a minimum preheat of 300°F (150°C)

(3) for pipe and tube materials meeting the requirements of (1)(a) through (1)(c) above having fillet welds attaching nonpressure parts tothem, provided the fillet weld has a throat thickness of 1⁄2 in. (13 mm) or less and the material is preheated to 300°F (150°C) minimum;or combination groove and fillet welds attaching nonpressure parts to pressure parts, with a weld thickness of 1⁄2 in. (13 mm) or less,and the material is preheated to a minimum of 300°F (150°C); or heat-absorbing surfaces and non-load-carrying studs attached to them,provided the material is preheated to 300°F (150°C) minimum. A lower preheating temperature may be used, provided specificallycontrolled procedures necessary to produce sound joints are used. Such procedures shall include but shall not be limited to the following:(a) the maximum throat thickness of fillet welds shall be 1⁄2 in. (13 mm)(b) the maximum continuous length of fillet welds shall be not over 4 in. (100 mm)(c) electrodes or filler metal shall be dry and shall provide a low-hydrogen weld deposit. Chromium-molybdenum filler metals shall have

a maximum specified chromium content of not more than 2.50% and a maximum specified carbon content of not more than 0.05%(d) the thickness of the test plate used in making the welding procedure qualification of Section IX shall not be less than that of the

material to be welded(4) for tubes or pressure retaining handhole and inspection plugs or fittings with a specified maximum chromium content of 6% that are

secured by physical means (rolling, shoulder construction, machine threads, etc.) and seal welded, provided the seal weld has a throatthickness of 3⁄8 in. (10 mm) or less, and preheat to a minimum temperature of 300°F (150°C) is applied when the thickness of eitherpart exceeds 5⁄8 in. (16 mm)

(5) for welds attaching nonload-carrying studs or insulation attachment pins not exceeding 1⁄2 in. (13 mm) in diameter when using an automaticarc stud welding or automatic resistance stud welding process

(6) for corrosion-resistant weld metal overlay of P-No. 5A pipe or tube, provided the following conditions are met:(a) a minimum preheat of 300°F (150°C) is applied when the thickness exceeds 1⁄2 in. (13 mm)(b) overlay is applied using GTAW or GMAW with a 360 deg spiral deposition technique(c) overlay cladding thickness does not exceed 1⁄8 in. (3 mm)(d) the tube or pipe material does not exceed NPS 5 (DN 125) and is not used as a drum or shell

(b) Postweld heat treatment is not mandatory for electric resistance welds used to attach extended heat-absorbing fins to pipe and tube materials,provided the following requirements are met:(1) a maximum pipe or tube size of NPS 4 (DN 100)(2) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a value

within the specification limits) of not more than 0.15%(3) a maximum fin thickness of 1⁄8 in. (3 mm)(4) prior to using the welding procedure, the Manufacturer shall demonstrate that the heat-affected zone does not encroach upon the minimum

wall thickness(c) General Note (a) does not apply to welds using the inertia and continuous drive friction welding processes. Postweld heat treatment is mandatory

for all thicknesses of materials welded using inertia and continuous drive friction welding.(d) Postweld heat treatment is not mandatory for attaching bare wire thermocouples by capacitor discharge welding or electric resistance welding

provided the following requirements are met:(1) The requirements of PW-39.8.(2) The maximum carbon content of the base material is restricted to 0.15%.(3) The minimum wall thickness shall be 0.20 in. (5.0 mm).

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Minimum Holding Time at Normal Temperaturefor Weld Thickness (Nominal)Minimum Holding Maximum Holding

Temperature, °F (°C) Temperature, °F (°C) Up to 5 in. Over 5 in.Material [Notes (1) and (2)] [Notes (3) and (4)] (125 mm) (125 mm)

P-No. 15E 1,350 (730) 1,425 (775) 1 hr/in. (1 hr/25 mm), 5 hr plus 15 min forGroup No. 1 30 min minimum each additional


GENERAL NOTES:(a) Postweld heat treatment is not mandatory for electric resistance welds used to attach extended heat-absorbing fins to pipe and tube materials,

provided the following requirements are met:(1) a maximum pipe or tube size of NPS 4 (DN 100)(2) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.15%(3) a maximum fin thickness of 1⁄8 in. (3 mm)(4) prior to using the welding procedure, the Manufacturer shall demonstrate that the heat-affected zone does not encroach upon the

minimum wall thickness(b) Postweld heat treatment is not mandatory for attaching bare wire thermocouples by capacitor discharge welding or electric resistance welding,

provided the following requirements are met:(1) The requirements of PW-39.8.(2) The maximum carbon content of the base material is restricted to 0.15%.(3) The minimum wall thickness shall be 0.20 in. (5.0 mm).

NOTES:(1) If the nominal weld thickness is ≤ 0.5 in. (13 mm), the minimum holding temperature is 1,325°F (720°C).(2) For dissimilar metal welds (i.e., welds made between a P-No. 15E Group 1 and another lower chromium ferritic, austenitic, or nickel-based

steel), if filler metal chromium content is less than 3.0% or if the filler metal is nickel-based or austenitic, the minimum holding temperatureshall be 1,300°F (705°C).

(3) The maximum holding temperature above is to be used if the actual chemical composition of the matching filler metal used when making theweld is unknown. If the chemical composition of the matching filler metal is known, the maximum holding temperature can be increased asfollows:(a) If Ni + Mn < 1.50% but ≥ 1.0%, the maximum PWHT temperature is 1,450°F (790°C).(b) If Ni + Mn < 1.0%, the maximum PWHT temperature is 1,470°F (800°C).

Explanatory Note to (3) Above: The lower transformation temperature for matching filler material is affected by alloy content, primarily thetotal of Ni + Mn. The maximum holding temperature has been set to avoid heat treatment in the intercritical zone.

(4) If a portion of the component is heated above the heat treatment temperature allowed above, one of the following actions shall be performed:(a) The component in its entirety must be renormalized and tempered.(b) If the maximum holding temperature in the table or Note (3)(a) above is exceeded, but does not exceed 1,470°F (800°C), the weld metal

shall be removed and replaced.(c) The portion of the component heated above 1,470°F (800°C) and at least 3 in. (75 mm) on either side of the overheated zone must be

removed and be renormalized and tempered or replaced.(d) The allowable stress shall be that for Grade 9 material (i.e., SA-213-T9, SA-335-P9, or equivalent product specification) at the design

temperature, provided that the portion of the component that was heated to a temperature exceeding the maximum holding temperatureis subjected to a final heat treatment within the temperature range and for the time required above. In order to apply the provisions ofthis paragraph, the Manufacturer must have qualified a WPS with representative test specimens that accurately simulate the thermalhistory of the production part. Specifically, the qualification specimens first must be heat treated at a similar temperature for a similartime that violated the maximum holding temperature limit and then must receive a final heat treatment for the required time within thetemperature range specified by this table.

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P-No. 6 1,400 (760) 1 hr/in. (1 hr/25 mm), 1 hr/in. (1 hr/25 mm) 5 hr plus 15 min forGroup No. 1,2,3 15 min minimum each additional



(1) for Type 410 material where the material and construction shall comply with the following conditions:(a) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification limits) of not more than 0.08%(b) the electrodes used shall produce an austenitic chromium-nickel weld deposit, or a non-air-hardening nickel-chromium-iron weld

deposit, and provided the following additional requirements are met:(1) the material thickness at the welded joint does not exceed 3⁄8 in. (10 mm)(2) or material thickness over 3⁄8 in. (10 mm) through 11⁄2 in. (38 mm), the following additional conditions shall be required:

(a) a preheat of 450°F (230°C) shall be maintained during welding(b) the welded joints shall be fully volumetrically examined


value within specification limits) of not more than 0.15%(c) a maximum fin thickness of 1⁄8 in. (3 mm)(d) prior to using the welding procedure, the Manufacturer shall demonstrate that the heat-affected zone does not encroach upon the

minimum wall thickness(b) General Note (a) does not apply to welds using the inertia and continuous drive friction welding processes. Postweld heat treatment is mandatory

for all thicknesses of materials welded using inertia and continuous drive friction welding.

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P-No. 7 1,350 (730) 1 hr/in. (1 hr/25 mm), 1 hr/in. (1 hr/25 mm) 5 hr plus 15 min forGroup No. 1,2 15 min minimum each additional


GENERAL NOTES:(a) Postweld heat treatment for P-No. 7 material shall be performed as described in PW-39.3, except that the cooling rate shall be a maximum

of 100°F/hr (55°C/hr) in the range above 1,200°F (650°C) after which the cooling rate shall be sufficiently rapid to prevent embrittlement.(b) Postweld heat treatment is not mandatory for P-No. 7 materials under the following conditions:

(1) for Type 405 material where the material and construction shall comply with the following conditions:(a) a maximum specified carbon content (SA material specification carbon content, except when further limited by the Purchaser to a

value within the specification) of not more than 0.08%(b) the electrodes used shall produce an austenitic chromium-nickel weld deposit, or a non-air-hardening nickel–chromium–iron weld

deposit, and provided the following additional requirements are met:(1) the material thickness at the welded joint does not exceed 3⁄8 in. (10 mm)(2) for material thickness over 3⁄8 in. (10 mm) through 11⁄2 in. (38 mm), the following additional requirements are met:

(a) a preheat of 450°F (230°C) shall be maintained during welding(b) the welded joints shall be fully volumetrically examined


value within the specification limits) of not more than 0.15%(c) a maximum fin thickness of 1⁄8 in. (3 mm)(d) prior to using the welding procedure, the Manufacturer shall demonstrate that the heat-affected zone does not encroach upon the

minimum wall thickness

Minimum Holding Time at Normal Temperature for Weld Thickness (Nominal)Minimum HoldingTemperature, °F Up to 2 in. Over 2 in. (50 mm) Over 5 in.

Material (°C) (50 mm) to 5 in. (125 mm) (125 mm)

P-No. 8 None None None None

GENERAL NOTE: Postweld heat treatment is neither required nor prohibited for joints between austenitic stainless steels of the P-No. 8 group.

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Minimum Holding Time at Normal TemperatureMinimumfor Weld ThicknessNormal Holding

Temperature, °F Up to 2 in. Over 2 in. (50 mm) Over 5 in.Material (°C) (50 mm) to 5 in. (125 mm) (125 mm)

P-No. 10H None None None NoneGroup No. 1

GENERAL NOTE: For the austenitic-ferritic wrought duplex stainless steels listed below, postweld heattreatment is neither required nor prohibited, but any heat treatment applied shall be performed as listedbelow and followed by liquid quenching or rapid cooling by other means.

Postweld Heat Treatment, Temperature, °FAlloy (°C)

S31803 1870–2010 (1020–1100)

Minimum Holding Time at Normal TemperatureMinimumfor Weld Thickness (Nominal)Holding

Temperature, Up to 2 in. Over 2 in. (50 mm) toMaterial °F (°C) (50 mm) 5 in. (125 mm) Over 5 in. (125 mm)

P-No. 10I 1,250 (675) 1 hr/in. (1 hr/25 mm), 1 hr/in. 1 hr/in.Group No. 1 15 min minimum (1 hr/25 mm) (1 hr/25 mm)

GENERAL NOTE: Postweld heat treatment for P-No. 10I (SA-268 TP446 material only) shall be performedas described in PW-39.3, except that the cooling rate shall be a maximum of 100°F/hr (55°C/hr) above1,200°F (650°C) after which the cooling rate shall be sufficiently rapid to prevent embrittlement.

110



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Temperature, Up to 2 in. Over 2 in. (50 mm) Over 5 in.Material °F (°C) (50 mm) to 5 in. (125 mm) (125 mm)


GENERAL NOTE: Postweld heat treatment is neither required nor prohibited for joints between materialsof the P-No. 31 group.









PW-39.5.1.2 By heating a circumferential bandaround the entire vessel with the welded connection locatedat the middle of the band. Provided the required soak bandaround the nozzle or attachment weld, as defined in PW-39.3, is heated to the required temperature and held forthe required time, as specified in Table PW-39, the remain-der of the circumferentially-heated band need not reachthe required post weld heat treatment temperature. Thetemperature within the heated band shall be controlled toprevent harmful gradients.

PW-39.5.2 Local areas around nozzles or weldedattachments in the larger radius sections of double curva-ture heads, or spherical shells or heads, may be post weldheat treated by heating a circular region around the nozzle.This region, or soak band, shall include the nozzle orwelded attachment and shall be measured from the centerof the nozzle or attachment. The soak band shall be a circlewhose radius is equal to the radius at the widest width ofthe width of the weld attaching the nozzle or attachmentto the shell, plus the thickness of the shell or head, or 2 in.(50 mm), whichever is less. The portion of the vesseloutside of the circular region shall be thermally shieldedusing blankets, brick, or other suitable insulation materialso that the temperature gradient is not harmful. A greater

111

amount of base material may also be heated to permittemperature gradient control.

PW-39.5.3 Nozzles that contain circumferentialwelds in close proximity to a vessel or shell have additionalthermal restraint imposed by this close proximity. Ade-quate length between the weld on the nozzle and the shellshall be provided so that the post weld heat treatment doesnot introduce harmful stresses at the nozzle attachmentweld. Alternatively, the weld may be post weld heat treatedby heating a full circumferential band around the entirevessel or shell, which shall include the nozzle in the centerof the band.

PW-39.6 In the case of local postweld heat treatmentof welded joints in pipes, tubes, and headers, the soak bandshall extend around the entire pipe tube or header.

PW-39.7 Electroslag welds in ferritic materials over11⁄2 in. (38 mm). in thickness at the joint shall be given agrain refining (austenitizing) heat treatment.

PW-39.8 Capacitor discharge or electric resistancewelding may be used for attaching bare wire thermocou-ples, without subsequent postweld heat treatment, providedthe energy output for welding is limited to a maximum

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TABLE PW-39.1ALTERNATE POSTWELD HEAT TREATMENT

REQUIREMENTS FOR CARBON ANDLOW ALLOY STEELS

(Applicable only when permitted in Table PW-39)

Decrease in Temperature Minimum Holding TimeBelow Minimum Specified [Note (1)] at Decreased

Temperature, °F (°C) Temperature, hr Notes

50 (28) 2 . . .100 (56) 4 . . .150 (83) 10 (2)200 (111) 20 (2)

NOTES:(1) Minimum holding time per inch (25 mm) for thickness up to and

including 2 in. (50 mm). Add 15 min per inch (25 mm) of thicknessfor thickness greater than 2 in. (50 mm).

(2) These lower postweld heat treatment temperatures permitted onlyfor P-No. 1, Group 1 and 2 materials.

125 W-sec, and any requirements specified in the applica-ble notes as found in Table PW-39 shall apply. A weldingprocedure specification shall be prepared, and the contentshall describe as a minimum the capacitor discharge equip-ment, the combination of materials to be joined, and thetechnique of application. Qualification of the welding pro-cedure is not required.

PW-40 REPAIR OF DEFECTSPW-40.1 Weld imperfections, such as cracks, pinholes,

and incomplete fusion, detected visually or by leakage testsor by the examinations described in PW-11 and found tobe rejectable, shall be removed by mechanical means orby thermal grooving processes, after which the joint shallbe rewelded and reexamined.

PW-40.2 When tube-to-header or tube-to-drum weldedjoints have already received the postweld heat treatmentrequired by PWT-11 and PW-39, minor local additionalwelding for rework of the joint or to improve the filletweld contour may be performed on the materials listed inPW-40.2(b) without repeating the postweld heat treatment,subject to all the following limitations:

(a) The depth of any rework welding below the surfaceshall not exceed the smaller of 10% of the thickness ofthe drum or header, or 50% of the wall thickness of the tube.

(b) The area to be rework welded shall be preheated toat least the minimum temperatures as indicated below forthe material

Material Minimum Preheat,°F (°C),Welding P-Number Group for Rework Welding

P-No. 3, Groups 1 and 2 200 (95)P-No. 4 250 (120)

P-No. 5A 300 (150)

112

(c) The tubes shall not exceed 4 in. (100 mm) O.D.,except for P-No. 1 material, which shall not exceed 65⁄8 in.(170 mm) O.D.

(d) The welding procedure used for the rework weldingshall have been qualified to the requirements of SectionIX for the thickness of rework welding to be performedand for the omission of postweld heat treatment.

PW-40.3 Defects in P-No. 3 Group Nos. 1 and 2 materi-als, and in the welds joining these materials, may be weldrepaired after the final PWHT but prior to the final hydro-static test. The welded repairs shall meet the requirementsbelow.

PW-40.3.1 Defect Removal for Base Materials.The defect shall be removed or reduced to an acceptablesize. Before repair welding, the groove shall be examinedto verify that the defect has been reduced to an acceptablesize, using either the magnetic particle or the liquid pene-trant examination methods. When the material is nonmag-netic, only the liquid penetrant method shall be used.Methods for magnetic particle examination and liquid pen-etrant examination shall be in accordance with A-260 andA-270, respectively; however, the acceptance standards forthe examination shall be in accordance with the require-ments of the original base material specification.

PW-40.3.2 Defect Removal for Welds and WeldedRepairs. The defect shall be removed, and the grooveexamined to verify defect removal, using either the mag-netic particle or the liquid penetrant examination methods.When the material is nonmagnetic, only the liquid penetrantmethod shall be used. Methods and acceptance standardsfor magnetic particle examination and liquid penetrantexamination shall be in accordance with A-260 or A-270,respectively.

PW-40.3.3 The total repair depth shall not exceed10% of the base material thickness. The total depth of aweld repair shall be taken as the sum of the depths forrepairs made from both sides of a weld at a given location.The total area of such repairs shall not exceed 100 in.2

(0.065 m2).

PW-40.3.4 In addition to the requirements of SectionIX for qualification of welding procedure specificationsfor groove welds, the following requirements shall apply:

(a) The weld procedure qualification shall have beenmade using material of the same P-No. and Group No. asthe material to be repaired. The specific welding techniqueor combination of welding techniques used shall have beendeveloped and tested to assure adequate tempering of theunderlying weld bead heat-affected zones.

(b) The weld metal shall be deposited by the manualshielded metal-arc process. Only low hydrogen weldingelectrodes shall be used. The electrodes shall be properlyconditioned in accordance with Section II, Part C, SFA-5.5, Appendix A6.12.



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(c) The maximum heat input for each weld layer shallnot exceed that used in the procedure qualification test.

(d) The maximum deposited weld bead width for anyelectrode shall be four times the electrode core diameter.

(e) The repair area, including a band equal in width to4 in. (100 mm) or four times the thickness of the weldrepair, whichever is greater, on either side of the groove,shall be preheated and maintained at a minimum tempera-ture of 350°F (175°C) during welding. The maximuminterpass temperature shall be 450°F (230°C).

(f) The repair weld method shall be limited to the halfbead weld repair technique as follows. The initial layer ofweld metal shall be deposited over the entire area using1⁄8 in. (3 mm) maximum diameter electrodes. Approxi-mately one half the thickness of this layer shall then beremoved by grinding before depositing subsequent layers.The subsequent weld layers shall be deposited using 5⁄32 in.(4 mm) maximum diameter electrodes, in such a manneras to assure tempering of the prior weld beads and theirheat affected zones. A final temper bead weld shall beapplied to a level above the surface being repaired withoutcontacting the base material, but close enough to the edgeof the underlying weld bead, to assure tempering of thebase material heat affected zone.

PW-40.3.5 For materials greater than 1 in. (25 mm)thick, after completing all welding, the repair area shallbe heated to and maintained at a temperature of 450°F to550°F (230°C to 290°C) for a minimum period of 4 hr.

PW-40.3.6 Any final temper bead reinforcementshall then be removed substantially flush with the surfaceof the base material.

PW-40.3.7 After the finished repair weld has reachedambient temperature, it shall be examined to the require-ments of PW-40.3.2, using the same nondestructive exami-nation technique that was used to examine the weld groove.

PW-40.3.8 The vessel shall be hydrostatically testedin accordance with PW-54.

PW-40.3.9 The Manufacturer shall obtain theapproval of the Authorized Inspector, prior to making therepair.

PW-41 CIRCUMFERENTIAL JOINTS INPIPES, TUBES, AND HEADERS

The rules in the following paragraphs apply specificallyto the boiler proper and parts thereof.

PW-41.1 Circumferential welded butt joints in pipe,tubes, and headers shall meet the radiographic and ultra-sonic examination requirements of Table PW-11.

PW-41.2 All circumferential arc or gas welded joints ofparts covered by this paragraph and welded in accordance

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therewith shall have a double-welded butt joint or a single-welded butt joint made the equivalent of a double-weldedbutt joint, except as otherwise provided in PW-41.4 andPW-41.5.

PW-41.2.1 The strength of the weld shall be suffi-cient to develop the full strength of the part in the longitudi-nal direction. There shall be no valley or groove along theedge or in the center of the weld except as permittedby PW-35.1. Weld reinforcement may be removed if sodesired. The design of the joint and the method of weldingshall be such that there will be no appreciable projectionof weld metal past the inside surface.

PW-41.2.2 In welding single-welded butt joints,complete penetration at the root is required. This shall bedemonstrated by the qualification of the procedure to beused. If complete penetration cannot otherwise be secured,the procedure shall include a backing ring or equivalent.The depth of weld measured between the inside surfaceof the weld preparation and the outside surface of thepipe or tube shall be not less than the minimum thicknesspermitted by the applicable material specifications for theparticular size and thickness of pipe or tubing used. Wherebacking rings are not used, concavity of the root surfaceis permitted if the depth of the concavity of the weld metaldoes not exceed the lesser of 3⁄32 in. (2.5 mm) or 20% ofthe thinner of the two sections being joined. The contourof the concavity shall be smooth and the resulting thicknessof the weld, including reinforcement, shall be at least equalto the required thickness of the thinner section. Concavitydepth allowed under the rules of this paragraph shall bereduced by an amount equal to any net section replacementused, as permitted in PW-41.2.3.

PW-41.2.3 When the wall is recessed for a backingring or to assure a uniform inside diameter of the weldpreparation, the depth of such recess shall be so limitedthat the remaining net section of the wall is not less thanthe minimum required thickness. For boiler and superheatertubes where the diameter does not exceed 4 in. (100 mm),the recess may reduce the required thickness by not morethan 1⁄32 in. (0.8 mm), provided the reduced net section isreplaced by weld metal in the outside reinforcement suchthat the resulting thickness of the weld, including reinforce-ment, is at least equal to the minimum required thickness.

PW-41.2.4 Backing rings may be of any size orshape suitable for the welding process and may be left inplace or removed as desired. Materials for backing ringsshall be compatible with the weld metal and base materialand shall not cause harmful alloying or contamination. Ifleft in place they must be properly secured to preventdislodgment and shall have a contour on the inside tominimize the restriction to flow, if needed, and be of suchinside diameter as to permit the passage of a tube cleanerwhere such cleaner is to be used.



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FIG. PW-43.1 METHOD OF COMPUTATION OF ATTACHMENTS TO TUBES

Wr W

eLug

/ 2Tube

PW-41.2.5 When welded joints in tubes or pipes arenot postweld heat treated, the procedure qualification testshall be made under the same conditions, but the perform-ance qualification test may be made on either postweldheat treated or nonpostweld heat treated samples.

PW-41.3 Pipe connections not exceeding NPS 1⁄2(DN 15) may be welded to pipe or headers under the provi-sions of this paragraph without the inspection required bythis Section.

PW-41.4 For attachment of nozzles to boiler drums orheaders see PW-15.

PW-41.5 Welded socket type joints or sleeve typejoints may be used to connect pipe or tubes to valves orfittings, or to each other, provided the conditions specifiedin PW-41.5.1 through PW-41.5.6 are met.

PW-41.5.1 Pipe shall not exceed NPS 3 (DN 80)and tubing shall not exceed 31⁄2 in. (89 mm) nominal outsidediameter (see PG-42, for ASME socket welding compo-nents).

PW-41.5.2 The depth of insertion of a pipe or tubeinto a socket shall be at least 1⁄4 in. (6 mm). There shall beat least 1⁄16 in. (1.5 mm) clearance between the end of thepipe or tube and the internal shoulder of the socket, beforewelding.

PW-41.5.3 The fit between the socket or sleeve andthe pipe or tube shall conform to applicable standards forsocket weld fittings, and in no case shall the inside diameterof the socket or sleeve exceed the outside diameter of thepipe or tube by more than 0.080 in. (2.03 mm).

PW-41.5.4 The average outside diameter of the hubor sleeve (collar or end portion of socket welding fittings)shall be sufficient to make the average hub or sleeve thick-ness not less than 1.09 times the nominal thickness of thepipe or tube.

PW-41.5.5 The throat dimension of the fillet weldshall be not less than 0.77 times the nominal thickness ofthe pipe or tube.

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PW-41.5.6 The depth of the insertion of a pipe ortube into a sleeve shall be at least 1⁄4 in. (6 mm). Thereshall be at least 1⁄16 in. (1.5 mm) clearance between thebutting ends of the pipe or tube, before welding.

PW-42 JOINTS IN VALVES AND OTHERBOILER APPURTENANCES

Valves, other boiler appurtenances such as water col-umns, and casings of pumps that are part of a boiler circula-tion system, may have fusion-welded joints other thanlongitudinal, complying with the requirements of this Partexcept that inspection of these joints is not required. TheManufacturer shall furnish, if requested, a statement certi-fying that these requirements have been met.

PW-43 LOADING ON STRUCTURALATTACHMENTS

PW-43.1 Loads imposed on steel tube walls by weldedor mechanical attachments, which produce bending stressesthat are additive to bursting stresses, shall conform to PW-43.1.1 and PW-43.1.2.

PW-43.1.1 The following inequality:L ≤ La

where

L p actual unit load calculated from PW-43.1.2La p maximum allowable unit load, lb /linear in. of

attachment from PW-43.2

PW-43.1.2 The following equation:L p Wr /� ± 6We/�2

where

e p eccentricity of W, (see Fig. PW-43.1)� p length of attachment of tube

W p eccentric load applied to lugWr p load component normal to tube axis

In determining the allowable loading per inch (25 mm)of length of attachment on a tube bend, the allowable unit

(10)

(10)



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2010 SECTION I

load determined by using the outside diameter of the tubeshall be increased by the amount of allowable compressionunit load for a tube having an outside diameter equivalentto the outside diameter of the bend and having a wallthickness the same as that of the tube bend (see Fig. A-74).For an alternative method of determining the maximumallowable loading on structural attachments to tubes, seeA-73.2 for conducting tests on full-size sections of tubes.

PW-43.2 Procedure for determining La in the equationin PW-43.1.1.Step 1: Determine K from Table PW-43.1.Step 2: Determine load factor, Lf, for compression or ten-

sion loading on lug from Fig. PW-43.2, or fromPW-43.2.1 or PW-43.2.2, when the range of thecurves in Fig. PW-43.2 does not extend farenough to cover specific cases.

PW-43.2.1 Compression Loading

Lf p 1.618X [−1.020 − 0.014 log X + 0.005 (log X)2]

PW-43.2.2 Tension Loading

Lf p 49.937X [−2.978 + 0.898 log X − 0.139 (log X)2]

Step 3: Determine St.

PW-43.2.3 Available Stress

St p 2.0 Sa − S

Step 4: Using values obtained in Steps 1 through 3, deter-mine maximum allowable unit load

PW-43.2.4 Allowable Unit Load

La p K(Lf)St

where

D p outside diameter of tubeK p tube attachment width design factor from Table

PW-43.1, dimensionlessLf p a compression or tension load factor

log p logarithm to base 10S p pressure stress in tube determined by the equation

in PG-27.2.1Sa p allowable stress value from Table 1A of Section

II, Part DSt p portion of allowable stress available for attach-

ment loading, from PW-43.2.3t p tube wall thickness

X p D / t 2, a parameter used to determine Lf

PW-44 FABRICATION RULES FORBIMETALLIC TUBES WHEN THECLAD STRENGTH IS INCLUDED

PW-44.1 The strengths for annealed wrought productsare listed in Section II, Part D, Tables 1A and 1B. Values

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applicable to either Section I or Section VIII, Div. 1 maybe used. The strength of deposited clad metal (welded orlaser fused) shall be inferred from an annealed wroughtmaterial with nominally equivalent strength and composi-tion as the clad (see PG-27.2.1.5, Note 11). The in-texttable below contains wrought alloys and weld wires thatmay be considered as nominally equivalent for this pur-pose. For powders used in laser-fused cladding, the depositchemistry shall nominally conform to that for weld wirefor welded cladding. For clad alloys that are not includedin the table below, the strength may be established byperforming tests in conformance with Appendix 5 of Sec-tion II, Part D and submitting the data to ASME foranalysis.

Generic Identity AWSWrought/Weld Wrought UNS No. Classification

309 or 309S/309 S30908 ER309None/309L None — use S30403 ER309LNone/312 None — use S30403 ER31233/33 R20033 None — matches

wrought chemistry600/82 N06600 ERNiCr-322/622 N06022 ERNiCrMo-10625/625 N06625 ERNiCrMo-3690/52 N06690 ERNiCrFe-7671/72 None — use N06600 ERNiCr-4825/None N08825 None

Some of the clad alloys are subject to embrittlementduring long-term service over specific temperature ranges.In particular, Alloy 625 embrittles in the temperature rangeof 1,000°F to 1,400°F (540°C to 760°C), and the ferritephase of 312 stainless steels embrittles above 500°F(260°C) with the shortest embrittlement time occurring at885°F (475°C) (see Section II, Part D, Appendix A, para.A-360).

PW-44.2 Rules governing the P-No. of the bimetallictube to which an attachment is welded are as follows:

(a) If the attachment is welded to the clad portion, theP-No. shall be that associated with the clad except whenthe combination of heat input and clad thickness create anew heat-affected zone in the core tube, in which casethe P-No. having the more conservative rules shall beapplicable. Macroetching and microhardness measuredfrom a representative sample may be used to determinewhether a new heat-affected zone is created in the coretube by the attachment welding.

(b) If the attachment is welded to the core, the P-No.shall be that associated with the core tube.

PW-44.3 The rules of Section IX applicable to corro-sion-resistant weld metal overlays (CRO) shall apply forwelding procedure qualifications and for welding perform-ance qualifications. In addition, qualification as a grooveweld in accordance with Section IX shall be satisfied todemonstrate strength and ductility of the weldment.



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TABLE PW-43.1TUBE ATTACHMENT ANGLE DESIGN FACTOR, K

Attachment angle

Angle ofattachment, deg 0 5 10 15 20 25 30 35 40 45

Designfactor, K 1.000 1.049 1.108 1.162 1.224 1.290 1.364 1.451 1.545 1.615

Angle ofattachment, deg 50 55 60 65 70 75 80 85 90

Designfactor, K 1.730 1.836 1.949 2.076 2.221 2.341 2.513 2.653 2.876

FIG. PW-43.2 CHART FOR DETERMINING LOAD FACTOR, Lf

210

1.8

3 4 5 6 7 8 9

X = D/t 2

Load

Fac

tor,

Lf

102 2 3 4 5 6 7 8 9 103

.6

.5

.4

.3

.2

10−1

.08

.06

.05

.04

.03

.02

10−2

10−3

.008

.006

.005

.004

.003

.002

Tension loading

Compression loading

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2010 SECTION I

PW-44.4 Exemptions to postweld heat treatment(PWHT) in PW-39 that are specific to corrosion-resistantweld metal overlay cladding of pipe or tube materials shallapply. When there are no such exemptions, PWHT is man-datory and shall be based on the core material in accordancewith PW-39.

PW-44.5 A stress relief to relax residual stresses andimprove ductility may be desirable before making coldbends on bimetallic tubing.

PW-44.6 Bimetallic tubes that are cold formed aftercladding may require post-forming heat treatments.

PW-44.6.1 For bimetallic tubes in which the coretube and clad are both austenitic materials (either steel ornickel-based alloy), the cold forming rules of PG-19 shallapply with the minimum heat treatment temperature beingthe highest applicable to the two alloys. For weld- or laser-fused cladding, the nominal wrought equivalents in PW-44.1 may be used.

PW-44.6.2 For bimetallic tubes in which the coreis ferritic and the clad austenitic (either steel- or nickel-based alloy), the forming limits in Table PG-19 that wouldinitiate a required solution heat treatment shall not beexceeded. For weld- or laser-fused cladding, the nominalwrought equivalents in PW-44.1 may be used.

PW-44.7 Demonstration of the cladding process toachieve a metallurgical bond and a clad that is free fromrejectable defects shall be by examination of a workman-ship bimetallic tube sample using cladding parameters thatare to be used in production. The bimetallic tube sampleshall have a minimum length of 7 in. (175 mm). Thissample shall be evaluated prior to the start of fabricationand repeated for a new sample anytime an essential variableis changed, using the methods described in paras. PW-44.7.1 through PW-44.7.4.

PW-44.7.1 Two 0.5 in. (13 mm)-long rings shall beremoved, one from each end, and the four available crosssections (the ends of the two rings) shall be inspected usingthe liquid penetrant technique in accordance with AppendixA-270 except for revisions to the acceptance criteria in (a)through (c) below. The basis for rejection of indicationson any of the examined surfaces shall be as follows:

(a) Any linear indication (length more than or equal tothree times the width) with a length of 1⁄16 in. (1.6 mm)or greater. Rejectable linear indications on two or moresurfaces shall constitute rejection of the cladding process.

(b) More than two isolated rounded indications on anysingle examined surface with a size of ≥50% of clad thick-ness or 1⁄16 in. (1.6 mm), whichever is less. Rounded indica-tions that are initially classified as nonrejectable shall befurther explored by either incremental sectioning or supple-mental NDE. Any such rounded indication that is deter-mined to extend 1⁄8 in. (3.2 mm) or more below the ring

117

surface shall be reclassified as a rejectable indication.Rejectable indications on more than two of the four exam-ined surfaces shall constitute rejection of the claddingprocess.

(c) Four or more rounded indications with a size of≥75% of clad thickness or 1⁄16 in (1.6 mm), whichever isless, in a line separated by 1⁄16 in. (1.6 mm) or less, edgeto edge. Rejectable indications on two or more of the fourexamined surfaces shall constitute rejection of the claddingprocess.

PW-44.7.2 After removal of the two rings, theremaining portion of the tube shall be split longitudinally,and the four available cross sections shall be inspectedusing the liquid penetrant technique in accordance withA-270, except for revisions to the acceptance criteria in(a) through (c) below. The basis for rejection of indicationson any of the four examined surfaces shall be as follows:

(a) Any linear indication (length more than or equal tothree times the width) with a length of 1⁄16 in. (1.6 mm)or greater. Rejectable linear indications on two or moresurfaces shall constitute rejection of the cladding process.

(b) More than two isolated rounded indications on anysingle examined surface with a size of ≥50% of clad thick-ness or 1⁄16 in. (1.6 mm), whichever is less. Rounded indica-tions that are initially classified as nonrejectable shall befurther explored by either incremental sectioning or supple-mental NDE. Any such rounded indication that is deter-mined to extend 1⁄8 in. (3.2 mm) or more below the surfaceshall be reclassified as a rejectable indication. Rejectableindications on two or more of the four examined surfacesshall constitute rejection of the cladding process.

(c) Four or more rounded indications with a size of≥75% of clad thickness or 1⁄16 in (1.6 mm), whichever isless, in a line separated by 1⁄16 in. (1.6 mm) or less, edgeto edge. Rejectable indications on one or more of the fourexamined surfaces shall constitute rejection of the claddingprocess.

PW-44.7.3 Ultrasonic examination (UT) may besubstituted for the examinations described in PW-44.7.1and PW-44.7.2, provided the following conditions aresatisfied:

(a) The examination shall be done in accordance withSection V, Article 4, with specific emphasis on the portionsrelating to cladding (T-432.2, T-434.1.4, T-434.4, andT-473).

(b) The procedures shall have sensitivity to identify andsize rejectable defects of the sizes identified inPW-44.7.1(a) through (c) and PW-44.7.2(a) through (c).

(c) Four areas shall be selected, each containing a 7 in.(175 mm) length of bimetallic tubing. These four lengthsshall be given a full clad volumetric and core-to-clad bond-line examination, and the acceptance or rejection of a singlelength or the group of four lengths collectively shall bebased on the criteria in PW-44.7.2(a) through (c).



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2010 SECTION I

PW-44.7.4 In the event the cladding process isrejected based on PW-44.7.1, PW-44.7.2, or PW-44.7.3,two recovery paths are available as follows:

(a) The amount of sampling shall be doubled from theprevious examination and a retest performed using thesame methods. Rejection of any grouping shall constituterejection of the process. In the event of a rejection of theprocess on the second attempt, the retest protocol may berepeated a third and final time.

(b) The cladding process parameters shall be changedto produce a new workmanship sample and the examinationprocess repeated from the beginning.

PW-44.8 The rules in this paragraph and its subpara-graphs are applicable to laser-fused cladding and weldedcladding but not to coextruded tubing. During productionof bimetallic tubes, the Manufacturer responsible for certi-fying the boiler unit shall establish a nondestructive exami-nation program, to be implemented by the claddingorganization, consisting of the elements described inPW-44.8.1 through PW-44.8.4 as a minimum.

PW-44.8.1 Visual examination (VT) shall be per-formed on 100% of the clad surface in accordance withSection V, Article 9. Any indication open to the surfaceshall additionally be subjected to liquid penetrant testing(PT) in accordance with A-270 and acceptance or rejectionbased on A-270.4. The portion of bimetallic tubing con-taining rejectable defects shall either be removed or thedefects repaired in accordance with PW-44.9.

PW-44.8.2 A minimum of 5% of the clad portionof bimetallic tubing shall be subjected to liquid penetranttesting (PT) in accordance with A-270 and acceptance orrejection based on A-270.4. The portion of bimetallic tub-ing containing rejectable defects shall either be removedor the defects repaired in accordance with PW-44.9.

PW-44.8.3 In the vicinity of all the areas identifiedfor PT in PW-44.8.2, clad thickness shall be measured ata location (or locations) identified by the Manufacturerresponsible for certifying the boiler unit. The means formeasuring the clad thickness shall be established by theManufacturer responsible for certifying the boiler unitusing calibration standards typical of the clad process. Allviolations of minimum clad thickness shall initiate a moreextensive thickness survey to establish the extent of theaffected area, and an engineering evaluation for dispositionshall be performed by the Manufacturer responsible forcertifying the boiler unit.

PW-44.8.4 Other elements that may be consideredfor inclusions in the production examination programinclude the following:

(a) validation of chemical composition of the clad, par-ticularly chromium

(b) documentation of dimensional characteristics of thecompleted component

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(c) records of clad areas for each weld consumable used(d) hardness testing(e) examining the clad surface with copper sulfate to

identify bare areas(f) macroscopic and microscopic metallographic sam-

pling

PW-44.9 Defects confined to the clad, revealed by theexaminations in PW-44.8 or found otherwise, that do notencroach on the minimum clad thickness or the minimumtotal wall thickness shall be removed locally by mechanicalmeans and the area smoothly blended to the adjacent con-tour. Defects that encroach on the minimum clad thicknessor the minimum total wall thickness shall be weld repairedin accordance with the applicable portions of PW-41. Allrepaired areas shall subsequently be inspected to therequirements of PW-44.8 and subparagraphs and shownto conform to the acceptance standards in A-270.


PW-46 GENERALPW-46.1 The rules in the following paragraphs apply

specifically to the inspection and testing of power boilersand power boiler parts that are fabricated by welding andshall be used in conjunction with the general requirementsfor inspection and tests in Part PG as well as the specificrequirements for inspection and tests in the applicable Partsof this Section that pertain to the type of boiler underconsideration.

PW-46.2 Inspection During Fabrication. The Manu-facturer shall submit the vessel or other pressure part forinspection at such stages of the work as may be designatedby the Inspector.

PW-47 CHECK OF WELDING PROCEDUREPW-47.1 It is the duty of the Inspector to assure himself

that the welding procedures employed in construction havebeen qualified under the provisions of Section IX. TheManufacturer shall submit evidence to the Inspector thatthose requirements have been met.

PW-47.2 The Inspector has the right at any time tocall for and witness the test welding and testing althoughit is not mandatory that he witness the test welding andthe testing unless he so desires.

PW-48 CHECK OF WELDER AND WELDINGOPERATOR PERFORMANCEQUALIFICATIONS

PW-48.1 It is the duty of the Inspector to assure himselfthat all welding is done by welders or welding operators



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2010 SECTION I

qualified under the provisions of Section IX. The Manufac-turer shall make available to the Inspector a certified copyof the record of performance qualification tests of eachwelder and welding operator as evidence that these require-ments have been met.

PW-48.2 The Inspector has the right at any time tocall for and witness the test welding and testing althoughit is not mandatory that he witness the test welding andthe testing unless he so desires.

PW-49 CHECK OF HEAT TREATMENTPRACTICE

The Inspector shall satisfy himself that all heat treatingoperations required by the Code have been correctly per-formed.

PW-50 QUALIFICATION OFNONDESTRUCTIVE EXAMINATIONPERSONNEL

PW-50.1 The Manufacturer shall be responsible forassuring that nondestructive examination (NDE) personnelhave been qualified and certified in accordance with theiremployer’s written practice prior to performing or evaluat-ing radiographic or ultrasonic examinations required bythis Section. SNT-TC-1A3 or CP-189 shall be used as aguideline for employers to establish their written practice.National or international Central Certification Programs,such as the ASNT Central Certification Program (ACCP),may be used to fulfill the examination and demonstrationrequirements of the employer’s written practice. Provisionsfor training, experience, qualification, and certification ofNDE personnel shall be described in the Manufacturer’squality control system (see PG-105.4).

PW-50.2 NDE personnel shall be qualified by examina-tion. Qualification of NDE Level III personnel certifiedprior to the 2004 Edition of Section I may be based ondemonstrated ability, achievement, education, and experi-ence. Such qualification shall be specifically addressed inthe written practice. When NDE personnel have been certi-fied in accordance with a written practice based on anedition of SNT-TC-1A or CP-189 earlier than that refer-enced in A-360, their certification shall be valid until theirnext scheduled recertification.

PW-50.3 Recertification shall be in accordance withthe employer’s written practice based on the edition ofSNT-TC-1A or CP-189 referenced in A-360. Recertifica-tion may be based on evidence of continued satisfactory

3 SNT-TC-1A, ACCP, and CP-189 are published by the AmericanSociety for Nondestructive Testing, 1711 Arlingate Lane, P.O. Box 28518,Columbus, OH 43228-0518.

119

performance or by reexamination(s) deemed necessary bythe employer.

PW-51 RADIOGRAPHIC EXAMINATIONPW-51.1 When the radiographic examination method

is used for a weld requiring volumetric examination byPW-11, the weld shall be examined throughout its entirelength by the X-ray or gamma-ray method in accordancewith Article 2 of Section V. The requirements of T-274are to be used as a guide but not for the rejection ofradiographs unless the geometrical unsharpness exceeds0.07 in. (1.8 mm).

PW-51.2 A single-welded circumferential butt jointwith backing strip may be radiographed without removingthe backing strip, provided it is not to be removed subse-quently and provided the image of the backing strip doesnot interfere with the interpretation of the resultant radio-graphs.

PW-51.3 Indications shown on the radiographs ofwelds and characterized as imperfections are unacceptableunder the following conditions, and shall be repaired asprovided in PW-40 and the repair radiographed to PW-51:

PW-51.3.1 Any indication characterized as a crack,or zone of incomplete fusion or penetration.

PW-51.3.2 Any other elongated indication on theradiograph that has a length greater than

(a) 1⁄4 in. (6 mm) for t up to 3⁄4 in. (19 mm)(b) 1⁄3 t for t from 3⁄4 in. (19 mm) to 21⁄4 in. (57 mm)(c) 3⁄4 in. (19 mm) for t over 21⁄4 in. (57 mm)

where t is the thickness of the weld

PW-51.3.3 Any group of aligned indications thathave an aggregate length greater than t in a length of 12t,except when the distance between the successive imperfec-tions exceeds 6L where L is the length of the longestimperfection in the group.

PW-51.3.4 Rounded indications in excess of thoseshown in A-250.

PW-51.4 A complete set of radiographs for each jobshall be retained by the Manufacturer and kept on file fora period of at least 5 years.

PW-52 ULTRASONIC EXAMINATIONPW-52.1 When the ultrasonic examination method is

used for a weld requiring volumetric examination byPW-11, the weld shall be examined throughout its entirelength using the techniques and standards for ultrasonicexamination as defined in Section V, Article 4, MandatoryAppendix VII, Ultrasonic Examination Requirements fora Workmanship Based Acceptance Criteria.

(10)

(10)

(10)

(10)



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(10)

2010 SECTION I

PW-52.2 The Manufacturer’s report, as required byT-490 of Section V, shall be retained by the Manufacturerfor a minimum of 5 yr.

PW-52.3 Acceptance-Rejection Standards. Imperfec-tions that cause an indication to exceed the evaluationlevels specified in Section V shall be investigated to theextent that the ultrasonic examination personnel can deter-mine their shape, identity, and location, and evaluate themin terms of PW-52.3.1 and PW-52.3.2.

PW-52.3.1 Cracks, lack of fusion, or incompletepenetration are unacceptable regardless of length.

PW-52.3.2 Other imperfections are unacceptable ifthe indication exceeds the reference level and their lengthexceeds the following:

(a) 1⁄4 in. (6 mm) for t up to 3⁄4 in. (19 mm)(b) 1⁄3t for t from 3⁄4 in. (19 mm) to 21⁄4 in. (57 mm)(c) 3⁄4 in. (19 mm) for t over 21⁄4 in. (57 mm)

where t is the thickness of the weld being examined. Ifthe weld joins two members having different thicknessesat the weld, t is the thinner of these two thicknesses.

PW-53 TEST PLATESPW-53.1 Vessel Test Plates. Cylindrical pressure parts

such as drums and shells that are subject to internal pressureand are fabricated by fusion welding, shall meet the testrequirements in PW-53.2 through PW-53.10. Cylindricalpressure parts such as pipe, tubes, and headers that aresubject to internal pressure, and all cylindrical pressureparts constructed of P-No. 1 materials, as defined in SectionIX, are exempt from these requirements.

PW-53.2 Welded Test Plates. A welded test plate hav-ing the dimensions shown in Fig. PW-53.1 shall be pre-pared from plate of the same material specification,4 thesame or greater thickness as the weld at the joint and usingthe same welding procedure as used for the shell platesthat it represents. The plate shall be welded by one of thefollowing methods.

PW-53.2.1 Attach the test plate as shown in Fig.PW-53.2 to one end of one longitudinal joint of each vesselso that the edges to be welded are a continuation of thecorresponding edges of the longitudinal joint. In this casethe weld metal shall be deposited in the weld joint of thetest plate continuously with that deposited in the shell joint.This procedure is not applicable to vessels with circumfer-ential joints only.

PW-53.2.2 Weld the joint in the test plate withoutattaching it as a continuation of a joint in the shell plate.

4 To be of the same specification as the steel being welded the chemicalcomposition must be within the specification limits and the melting prac-tice, i.e., killed, semikilled, or rimmed, must be the same.

120

PW-53.3 When noncylindrical pressure parts are notintegral with the vessel, a test plate shall be provided havinga thickness not less than that of the parts.

PW-53.4 Where there are several pressure parts of anyone design being welded in succession, and in which theplates are of the same material that is covered by thewelding procedure, a test plate shall be furnished for each200 ft (60 m), or fraction thereof, of the main weldedjoints. The thickness of the thinnest plate and of the thickestplate shall not differ by more than 1⁄4 in. (6 mm).

PW-53.5 Where more than one welder or welding oper-ator is used on a vessel, the inspector may designate thewelder or welding operator who shall make the requiredtest plate.

PW-53.6 The test plate shall be so supported that thewelding does not warp the plate out of line by an anglegreater than 5 deg. The plate shall be straightened beforepostweld heat treatment to remove any warping that hasoccurred. The test plate shall be given the same preheattreatment and the same postweld heat treatment as thevessel that it represents. In no case shall the temperatureof preheat or postweld heat treatment be higher than thatused for the vessel.

PW-53.7 Test Specimens. The coupons for tension andbend test shall be removed as shown in Fig. PW-53.1 andshall be of the dimensions shown in Figs. PW-53.3 (a) and(b). If the dimensions of the weld groove are such that afull size tension specimen cannot be obtained, then a smallsize specimen as shown in Fig. 4 of SA-370 may be used.The specimen removed shall be the largest specimen thatcontains only all-weld metal in the reduced section.

PW-53.8 Tension TestsPW-53.8.1 Except as provided in PW-53.8.5 two

types of tension test specimen are required, one of the jointand the other of the weld metal.

PW-53.8.2 The tension specimen of the joint shallbe transverse to the welded joint and shall be the fullthickness of the welded plate after the outer and innersurfaces of the weld have been machined to a plane surfaceflush with the surface of the plate. When the capacity ofthe available testing machine does not permit testing aspecimen of the full thickness of the welded plate, thespecimen may be cut with a thin saw into as many portionsof the thickness as necessary, each of which shall be testedand shall meet the requirements.

PW-53.8.3 If the transverse tension test specimenbreaks in the weld, its tensile strength shall be not lessthan the minimum of the specified tensile range of the basematerial (The tension test of the joint specimen as specifiedherein is intended as test of the welded joint and not ofthe plate.). When the specimen breaks outside the weld at



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2010 SECTION I

FIG. PW-53.1 TEST SPECIMENS FROM LONGITUDINAL WELDED TEST PLATES

Weld

Gage lines

Bend test specimen

Sufficient length to accommodate all specimens

Tension specimen (all weld metal)

6 in

. (15

0 m

m)

+ 6t

b

ut

no

t le

ss t

han

10

in. (

250

mm

)

1.5 T

T

Dis

card

Ten

sio

n s

pec

imen

(tr

ansv

erse

)

Weld

Gage lines

Tension specimen

Sm

all

Siz

eS

pe

cim

en

Fu

ll S

ize

Sp

ecim

en

Edges of widest face of weld

Pla

teT

hic

kn

ess

Dis

card

FIG. PW-53.2 METHOD OF FORMING LONGITUDINAL TEST PLATES

Drum shell

Reinforcing bars clamped or welded to back of test plates. Test plates to be tack welded to the shell or otherwise supported in postion.

Test plates

Test plate Test plate

Reinforcing bars

Shell Shell

121



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2010 SECTION I

not less than 95% of the minimum of the specified tensilerange of the base material and the weld shows no signof weakness, the test shall be accepted as meeting therequirements. When the specimen or a portion thereofbreaks in the base material below this strength tolerancebecause of a local defect, one additional specimen shallbe tested and shall meet the requirements.

PW-53.8.4 The tension test specimen of the weldmetal shall be taken such that the reduced portion of thespecimen shall consist entirely of deposited weld metaland shall meet the following requirements:

Tensile strengthpat least that of the minimum of the rangeof the plate which is welded

Elongation, minimum, %, in 2 in. (50 mm) p 20,

or p 700/U + 10 (U.S. customary units), whicheveris less

p 4 820/U + 10 (SI units), whichever is less

where

U p minimum specified tensile strength of the materialto be welded, ksi (MPa), as given in the applicablestress table.

If small size tensile specimens are used, measurementof elongation may be omitted.

PW-53.8.5 For plate thicknesses less than 5⁄8 in.(16 mm), the all-weld metal tension test may be omitted.

PW-53.9 Bend TestsPW-53.9.1 The bend test specimen shall be trans-

verse to the welded joint of the full thickness of the plateand shall be of rectangular cross section with a width 11⁄2times the thickness of the specimen. When the capacity ofthe available testing machines does not permit testing aspecimen of the full thickness of the welded plate, thespecimen may be cut with a thin saw into as many portionsof the thickness as necessary, each of which shall be testedand shall meet the requirements. The inside and outsidesurfaces of the weld shall be machined to a plane surfaceflush with the surface of the specimen. The edges of thissurface shall be rounded to a radius not over 10% of thethickness of the test specimen. The specimen shall be bentcold under free bending conditions until the least elonga-tion measured within or across approximately the entireweld on the outside fibers of the bend test specimen is30%, or 700/U (4 820/U) + 20%, whichever is less.

where

U p minimum specified tensile strength of the materialto be welded, psi, as given in the applicablestress table

PW-53.9.2 When a crack is observed in the tensilestrained surface of the specimen between the edges before

122

the elongation required in PW-53.9.1 is attained, the speci-men shall be considered to have failed and the test shallbe stopped. Cracks at the corners of the specimen shallnot be considered as a failure. The appearance of smallimperfections in the convex surface shall not be consideredas a failure if the greatest dimension does not exceed 1⁄8 in.(3 mm).

PW-53.10 RetestsPW-53.10.1 Should any of the specimens fail to

meet the requirements by more than 10%, no retest shallbe allowed except that in the case of failure of the free-bend test specimen due to permissible types of imperfec-tions, free-bend specimen retests may be allowed at thediscretion of the Inspector.

PW-53.10.2 Should any of the specimens fail tomeet the requirements by 10% or less, retests shall beallowed. A second test plate shall be welded by the sameoperator who welded the plate which did not meet the testrequirements. The retest shall be made on specimens cutfrom the second plate.

PW-53.10.3 The retests shall comply with therequirements. For either of the tension retests, two speci-mens shall be cut from the second test plate, and both ofthese shall meet the requirements.

PW-53.10.4 When there is more than one specimenof the same type and one or more of the specimens fail tomeet the requirements by 10% or less, a retest may bemade for each specimen required for the weld under consid-eration. Each such specimen shall meet the requirements.

PW-53.10.5 If the percentage of elongation of all-weld metal tension specimen is less than that specified andany part of the fracture is more than 3⁄4 in. (19 mm) fromthe center of the 2 in. (50 mm) gage length of the specimen,a retest shall be allowed.

PW-54 HYDROSTATIC TESTPW-54.1 Except as modified in PG-99.3, PG-106.8,

and PW-54.3, all welded drums and other welded pressureparts shall be subjected to a hydrostatic test pressure ofnot less than 1.5 times the maximum allowable workingpressure. The hydrostatic test may be made either in theManufacturer’s shop or in the field.

PW-54.2 When repairs are made, the part shall againbe tested in the regular way, and if it passes the test theInspector shall accept it. If it does not pass the test theInspector may permit supplementary repairs, or if in hisjudgment the pressure part is not suitable for service, hemay permanently reject it.

PW-54.3 Welding of nonpressure parts to pressureparts and seal welding of pressure retaining handhole andinspection plugs or fittings secured by physical means may



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2010 SECTION I

FIG. PW-53.3(a) DETAILS OF TENSION TEST SPECIMENS

T

A

T

[Note (1)]

[Note (2)]

1/2 in. (13 mm) ±0.01 (0.2 mm)

Not less than 1/8 in. (3.0 mm)

B

T

21/2 in. (64 mm) 3/4 in. (19 mm)3/4 in. (19 mm)

21/4 in. (57 mm)

Full Size All Weld Metal Tension Specimen

Small Size All Weld Metal Tension Specimen[Note (9)]

t

10 in

. (25

0 m

m)

app

rox.

Note (5)

Note (3)Note (4)

Note (7)

[Note (8)]

1/4 in. (6 mm)

2 in. (50 mm)r

1/4 in. (6 mm)

1/4 in. (6 mm)

Transverse Tension Specimen

Transverse Tension Specimen

Note (6)

Note (6)

Note (3)W

NOTES:(1) A — Cross section through tension specimen.(2) B — Cross section through tension specimens on very thick plate.(3) Weld reinforcement shall be machined flush with base metal.(4) Edge of widest face of weld.(5) This section machined preferably by milling.(6) “f ” indicates light finish cut.(7) These edges may be flame cut.(8) W p 11⁄2 in. (38 mm) ± 0.01 in. (0.2 mm) if t does not exceed 1 in. (25 mm); W p 1 in. (25 mm) ± 0.01 in. (0.2 mm) if t exceeds 1 in.

(25 mm).(9) Specimen sizes in accordance with Fig. 4 of SA-370.

123



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2010 SECTION I

FIG. PW-53.3(b) DETAILS OF BEND TEST SPECIMENS

W =1.5 T

T

W =1.5 T

T

t

R = not over 0.1 T

R = not over 0.1 t

Cross Section ofBend Test Specimen

Cross Section ofBend Test SpecimensFrom Very Thick Plate

W

1/8 in. (3 mm) min.

1/16 in. (1.5 mm)

Tension surface

1/16 in. (1.5 mm)

[Note (2)]

T

Note (1)

1/8 in. (3 mm) min.

Edge of widestface of weld

f

f

f

f

f

f

ff

f

f

f

f

f

NOTES:(1) If coupons have been cut apart by a fusion process, the flame cut surfaces are to be machined off as indicated.(2) This surface to be reasonably smooth. Any tool marks remaining must be lengthwise of specimen. “f” indicates light finish cut. Weld reinforcement

to be removed.

be performed after the hydrostatic test without requiringanother hydrostatic test provided the following criteriaare met.

PW-54.3.1 Welding is done in conformance withthis Part and the completed weld is inspected by the Author-ized Inspector. The Manufacturers’ Data Report Form shallbe signed only after completion of the welding.

PW-54.3.2 For nonpressure parts welded to pressureparts, the following additional conditions shall be met:

(a) The pressure part material is limited to P-No. 1materials.

(b) The nonpressure attachment material is limited tocarbon steel with a carbon content not exceeding 0.2% orany P-No. 1 material.

124

(c) The welding is done by stud welding or by filletwelding having a throat not exceeding the lesser of 0.70times the thickness of the pressure part or 1⁄4 in. (6 mm).

(d) A minimum 200°F (95°C) preheat shall be appliedwhen the pressure part thickness exceeds 3⁄4 in. (19 mm).

PW-54.3.3 For seal welding of pressure retaininghandhole and inspection plugs or fittings secured by physi-cal means, the following additional conditions shall be met:

(a) The seal welds must be exempted from postweldheat treatment by rules elsewhere in this section.

(b) The completed weld is examined using either themagnetic particle or liquid penetrant examination methodin accordance with A-260 or A-270, respectively. Whenthe base materials or welds are nonmagnetic, only the liquidpenetrant method shall be used.



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2010 SECTION I

PART PRREQUIREMENTS FOR BOILERS

FABRICATED BY RIVETING

Manufacturers using riveted construction shall use the 1971 Edition of Section I. Boilers or parts thereof constructedby using riveted construction require the use of the applicable Manufacturer’s Data Report Forms as included in the1971 Edition of Section I.

125



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2010 SECTION I

PART PBREQUIREMENTS FOR BOILERS

FABRICATED BY BRAZING

GENERALPB-1 GENERAL

PB-1.1 Scope. The rules in Part PB are applicable topressure parts of boilers, including piping constructedunder the provisions of this Section, that are fabricated bybrazing. These rules shall be used in conjunction with thegeneral requirements in Part PG and the specific require-ments in the applicable Parts of this Section that pertainto the type of boiler under consideration. The rules in PartPB are not applicable to nonpressure bearing attachmentsto pressure parts that have essentially no load-carryingfunction (such as extended heat transfer surface, insulationsupport pins, etc.).

PB-1.1.1 Definition of Brazing. A group of weldingprocesses that produces coalescence of materials by heatingthem to the brazing temperature in the presence of a fillermetal having liquidus above 840°F (450°C) and below thesolidus of the base metal. The filler metal is distributedbetween the closely fitted faying surfaces of the joint bycapillary action.

PB-1.1.2 Brazing processes that are permitted foruse under this Part are classified by method of heating asfollows:

(a) torch brazing(b) furnace brazing(c) induction brazing(d) resistance brazing(e) dip brazing — salt and flux bath

PB-1.2 Elevated Temperature. Maximum design tem-perature is dependent on the brazing filler metal and onthe base metals being joined. The maximum design temper-atures for some brazing filler metals are shown in TablePB-1.

PB-1.3 Service Restrictions. Brazed components maybe used for service up to the temperatures as shown inTable PB-1, provided acceptable qualification tests are per-formed.

PB-1.4 Responsibility. Each Manufacturer1 (Certifi-cate of Authorization Holder) is responsible for the brazing

1 Manufacturer includes contractor, Assembler, and installer.

126

done by his organization and shall establish the proceduresand conduct the tests required by Section IX, and whennecessary those required by this Section to qualify thebrazing procedures used in the construction of brazedassemblies and the performance tests of brazers2 who applythese procedures. Such brazing will ordinarily be done byemployees of the Manufacturer who accepts the responsi-bility for Code construction of the boiler or part beingbrazed. Alternatively, the Manufacturer may perform Codebrazing using the services of individual brazers who arenot in his employ provided all the following conditionsare met.

PB-1.4.1 All Code construction shall be the responsi-bility of the Manufacturer.

PB-1.4.2 All brazing shall be performed in accor-dance with Manufacturer’s brazing procedure specifica-tions that have been qualified by the Manufacturer inaccordance with the requirements of Section IX and whennecessary, based on design temperature, with the additionalrequirements of this Section.

PB-1.4.3 All brazers shall be qualified by the Manu-facturer in accordance with the requirements of Section IX.

PB-1.4.4 The Manufacturer’s quality control systemshall include the following as a minimum.

PB-1.4.4.1 A requirement for complete and exclu-sive administrative and technical supervision of all brazersby the Manufacturer.

PB-1.4.4.2 Evidence of the Manufacturer’sauthority to assign and remove brazers at his discretionwithout involvement of any other organization.

PB-1.4.4.3 A requirement for assignment ofbrazer identification symbols.

PB-1.4.4.4 Evidence that this program has beenaccepted by the Manufacturer’s Authorized InspectionAgency.

PB-1.4.5 The Manufacturer shall be responsible forCode compliance of the brazement including Code symbol

2 Brazer includes brazing operator.



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2010 SECTION I

TABLE PB-1MAXIMUM DESIGN TEMPERATURES [°F (°C)] FOR BRAZING FILLER METAL

Temperature BelowFiller Metal Which Section IX Tests Temperature Range RequiringClassification Only Are Required, °F (°C) Section IX and Additional Tests, °F (°C)

BCuP 300 (150) 300–350 (150–175)BAg 400 (205) 400–500 (205–260)BCuZn 400 (205) 400–500 (205–260)BCu 400 (205) 400–650 (205–345)BAlSi 300 (150) 300–350 (150–175)BNi 1,200 (650) 1,200–1,500 (650–815)BAu 800 (425) 800–900 (425–480)BMg 250 (120) 250–275 (120–135)

GENERAL NOTE: Temperatures based on AWS recommendations.

stamping and providing Data Report Forms properly exe-cuted and countersigned by the Authorized Inspector.

MATERIALS

PB-5 GENERALPB-5.1 Materials used in brazed construction of pres-

sure parts shall conform to one of the specifications givenin Section II and shall be limited to those specificallypermitted in Parts PG, PWT, and PFT for which allowablestress values are given in Tables 1A and 1B of Section II,Part D for Section I Construction, and for which brazinggroup P-Numbers are assigned in Section IX.

PB-5.2 Combinations of Dissimilar Metals. Combina-tions of dissimilar metals may be joined by brazing pro-vided they meet the qualification requirements of SectionIX and this Section.

PB-6 BRAZING FILLER METALS

The selection of the brazing filler metal for a specificapplication shall depend upon its suitability for the basemetals being joined and the intended service. Satisfactoryqualification of the brazing procedure under Section IXand when necessary based on design temperature, with theadditional requirements of this Section, is considered proofof the suitability of the filler metal. Brazing with brazingfiller metals other than those listed in Section II, Part C,SFA-5.8 shall be separately qualified for both procedureand performance qualification in accordance with SectionIX and when necessary with the additional requirementsof this Section.

PB-7 FLUXES AND ATMOSPHERES

Suitable fluxes or atmospheres or combinations of fluxesand atmospheres shall be used to prevent oxidation of the

127

brazing filler metal and the surfaces to be joined. Satisfac-tory qualification of the brazing procedure under SectionIX and when necessary, based on design temperature, withthe additional requirements of this Section, is consideredproof of the suitability of the flux and/or atmosphere.

DESIGN

PB-8 GENERAL

The rules in the following paragraphs apply to boilersand parts thereof that are fabricated by brazing and shallbe used in conjunction with the general requirements fordesign in Part PG, as well as with the specific requirementsfor design in the applicable Parts of this Section that pertainto the type of boiler under consideration.

PB-9 STRENGTH OF BRAZED JOINTS

It is the responsibility of the Manufacturer to determinefrom suitable tests or from experience that the specificbrazing filler metal selected can produce a joint which willhave adequate strength at design temperature. The strengthof the brazed joint shall not be less than the strength ofthe base metal, or the weaker of the two base metals inthe case of dissimilar metal joints.

PB-9.1 Qualification of Brazed Joints for DesignTemperatures Up to the Maximum Shown in Column1 of Table PB-1. Satisfactory qualification of the brazingprocedure in accordance with part QB of Section IX isconsidered evidence of the adequacy of the base materials,the brazing filler metal, the flux and/or atmosphere, andother variables of the procedure.

PB-9.2 Qualification of Brazed Joints for DesignTemperatures in the Range Shown in Column 2 ofTable PB-1. For design temperatures in the range shownin Column 2 of Table PB-1, tests in addition to those in



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2010 SECTION I

PB-9.1 are required. These tests shall be considered a partof the qualification procedure. For such design tempera-tures, two tension tests on production type joints arerequired, one at the design temperature and one at 1.05T[where T is the design temperature in degrees Fahrenheit(or degrees Celsius)]. Neither of these production-typejoints shall fail in the braze metal.

PB-10 BRAZED JOINT EFFICIENCY

The joint efficiency factor to be used in design of boilerswith brazed joints shall be 1 for all joints.

PB-14 APPLICATION OF BRAZING FILLERMETAL

The design of the joint shall provide for the applicationof the brazing filler metal. Where practicable, the brazingfiller metal shall be applied in such a manner that it willflow into the joint or be distributed across the joint andproduce visible evidence that it has penetrated the joint.

PB-14.1 Manual Application. The manual applicationof the brazing filler metal by face-feeding to a joint shouldbe from one side only. Visual observation of the other sideof the joint will then show if the required penetration ofthe joint by the filler metal has been obtained.

PB-14.2 Preplaced Brazing Filler Metal. The brazingfiller metal may be preplaced in the form of slugs, powder,rings, strip, cladding, spraying, or other means. After braz-ing, the brazing filler metal should be visible on both sidesof the joint.

PB-15 PERMISSIBLE TYPES OF JOINTS

Some permissible types of brazed joints are shown inFig. PB-15. Lap joints shall have a sufficient overlap toprovide a higher strength in the brazed joint than in thebase metal.

The nominal thickness of base material used with lapjoints tested using the test fixture shown in Section IX,QB-462.1(e) shall not exceed 1⁄2 in. (13 mm). There is nothickness limitation when specimens are tested without thetest fixture shown in QB-462.1(e).

PB-16 JOINT CLEARANCE

The joint clearance shall be kept sufficiently small sothat the filler metal will be distributed by capillary action.Since the strength of a brazed joint tends to decrease asthe joint clearance is increased, the clearance for the assem-bly of joints in pressure vessels or parts thereof shall bewithin the tolerances set up by the joint design and used

128

for the corresponding qualification specimens made inaccordance with Section IX.

NOTE: For guidance, see Table PB-16, which gives recommended jointclearances at brazing temperature for varying types of brazing filler metal.Brazing alloys will exhibit maximum strength if clearances are maintainedwithin these limits.

PB-17 JOINT BRAZING PROCEDURE

A joint brazing procedure shall be developed for eachdifferent type of joint of a brazed assembly. A recom-mended form for recording the brazing procedure is shownin QB-482 of Section IX. If more than one joint occurs ina brazed assembly, the brazing sequence shall be specifiedon the drawing or in instructions accompanying the draw-ing. If welding and brazing are to be done on the sameassembly, the welding shall precede the brazing unless itis determined that the heat of welding will not adverselyaffect the braze previously made.

PB-18 OPENINGS

PB-18.1 Openings for nozzles and other connectionsshall be far enough away from any main brazed joint sothat the joint and the opening reinforcement plates do notinterfere with one another.

PB-18.2 Openings for pipe connections in boilers hav-ing brazed joints may be made by inserting pipe couplings,or similar devices not exceeding NPS 3 (DN 80) in theshell or heads and securing them by welding provided thewelding is performed by welders who have been qualifiedunder the provisions of Section IX for the welding positionand type of joint used. Such attachments shall conform tothe rules for welded connections PW-15 and PW-16.

PB-19 BRAZED CONNECTIONS

PB-19.1 Connections such as saddle type fittings andfittings inserted into openings formed by outward flangingof the vessel wall, in sizes not exceeding NPS 3 (DN 80),may be attached to boilers by lap joints of brazed construc-tion. Sufficient brazing shall be provided on either side ofthe line through the center of the opening parallel to thelongitudinal axis of the shell to develop the strength of thereinforcement through shear in the brazing.

PB-19.2 For nozzle fittings having a bolting flange andan integral flange for brazing, the thickness of the flangeattached to the boiler shall not be less than the thicknessof the neck of the fitting.



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2010 SECTION I

FIG. PB-15 SOME ACCEPTABLE TYPES OF BRAZED JOINTS

Lap

(a) Simple Lap Joint (d) Scarf Joint

(b) Straight Butt Joint (e) Butt Lap Joint

(c) Tee Joint

(g) Strapped Butt Joint

(f) Rabbet Joint

TABLE PB-16RECOMMENDED JOINT CLEARANCE AT

BRAZING TEMPERATURE

Clearance [Note (1)]

Brazing Filler Metal in. mm

BAlSi 0.006–0.010 for laps 0.15–0.25 for lapsless than or equal to 1⁄4 in. less than or equal to 6 mm

0.010–0.025 for laps 0.25–0.64 for lapsgreater than 1⁄4 in. greater than 6 mm

BCuP 0.001–0.005 0.02–0.13BAg 0.002–0.005 0.05–0.13BCuZn 0.002–0.005 0.05–0.13BCu 0.000–0.002 [Note (2)] 0.000–0.05 [Note (2)]BNi 0.001–0.005 0.02–0.13

NOTES:(1) In the case of round or tubular members clearance on the radius is intended.(2) For maximum strength use the smallest possible clearance.

FABRICATION

PB-26 GENERAL

The rules in the following paragraphs apply specificallyto the fabrication of boilers and parts thereof that are fabri-cated by brazing and shall be used in conjunction with thegeneral requirements for fabrication in Part PG, as well asthe specific requirements for fabrication in the applicableParts of this Section that pertain to the type of boiler underconsideration.

129

PB-28 QUALIFICATION OF BRAZINGPROCEDURE

PB-28.1 Each brazing procedure shall be recorded indetail by the Manufacturer. Each brazing procedure shallbe qualified in accordance with Section IX and when neces-sary determined by design temperature with the additionalrequirements of this Section.

PB-28.2 Brazing of all test coupons shall be conductedby the Manufacturer. Testing of all test coupons shall be



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2010 SECTION I

the responsibility of the Manufacturer. Qualification of abrazing procedure by one Manufacturer shall not qualifythat procedure for any other Manufacturer, except as pro-vided in QB-201 of Section IX.

PB-29 QUALIFICATION OF BRAZERS ANDBRAZING OPERATORS

PB-29.1 The brazers and brazing operators used inbrazing pressure parts shall be qualified in accordance withSection IX.

The qualification test for brazing operators of machineor furnace brazing equipment shall be performed on aseparate test plate prior to the start of brazing or on thefirst work piece.

PB-29.2 Each brazer or brazing operator shall beassigned an identifying number, letter, or symbol by theManufacturer that shall be used to identify the work ofthat brazer or brazing operator.

PB-29.3 The Manufacturer shall maintain qualificationrecords of the brazers and brazing operators showing thedate and result of tests and the identification mark assignedto each. These records shall be certified by the Manufac-turer by signature or some other method of control inaccordance with the Manufacturer’s Quality Control Sys-tem and be accessible to the Inspector.

PB-29.4 Brazing of all test coupons shall be conductedby the Manufacturer. Testing of all test coupons shall bethe responsibility of the Manufacturer. A performancequalification test conducted by one Manufacturer shall notqualify a brazer or brazing operator to do work for anyother Manufacturer.

PB-30 CLEANING OF SURFACES TO BEBRAZED

The surfaces to be brazed shall be clean and free fromgrease, paint, oxides, scale, and foreign matter of any kind.Any chemical or mechanical cleaning method may be usedthat will provide a surface suitable for brazing.

PB-31 CLEARANCE BETWEEN SURFACESTO BE BRAZED

The clearances between surfaces to be brazed shall bemaintained within the tolerances provided for by the jointdesign and used in the qualifying procedure. If greatertolerances are to be used in production, the joint mustbe requalified for those greater tolerances. The control oftolerances required may be obtained by using spot welding,crimping, or other means that will not interfere with the

130

quality of the braze. If such means are employed in produc-tion, they must also be employed in qualification of proce-dure, brazer, and operator.

PB-32 POSTBRAZING OPERATIONS

Brazed joints shall be thoroughly cleaned of flux residueby any suitable means after brazing and prior to inspection.3

Other postbrazing operations such as thermal treatmentsshall be performed in accordance with the qualified pro-cedure.

PB-33 REPAIR OF DEFECTIVE BRAZING

Brazed joints that have been found to be defective maybe rebrazed, where feasible, after thorough cleaning, byemploying the same brazing procedure used for the originalbraze. If a different brazing procedure is employed, i.e.,torch repair of furnace brazed parts, a repair brazing proce-dure shall be established and qualified.

When a repair brazing procedure is established it shallmeet Section IX and other conditions set forth in thisSection.


PB-46 GENERALPB-46.1 The rules in the following paragraphs apply

specifically to the inspection and testing of power boilerparts that are fabricated by brazing and shall be used inconjunction with the general requirements for inspectionand tests in Part PG as well as the specific requirementsfor inspection and tests in the applicable Parts of this Sec-tion that pertain to the type of boiler under consideration.

PB-46.2 Inspection During Fabrication. The Manu-facturer shall submit the boiler or other pressure part forinspection at such stages of the work as may be designatedby the Inspector.

PB-47 CHECK OF BRAZING PROCEDUREPB-47.1 The Inspector shall assure himself that the

brazing procedure for each type of joint being producedis qualified in accordance with the requirements of SectionIX and when necessary the additional requirements of thisSection. He shall satisfy himself that each joint has beenfabricated in accordance with the procedure. Where thereis evidence of consistent poor quality, the Inspector shallhave the right at any time to call for and witness tests ofthe brazing procedure.

3 Flux residues can be extremely corrosive as well as interfering withvisual inspection.



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2010 SECTION I

PB-48 BRAZER AND BRAZING OPERATORPB-48.1 The Manufacturer shall certify that the brazing

on a boiler or part thereof has been done by brazers orbrazing operators who are qualified under the requirementsof Section IX. The Inspector shall assure himself that onlyqualified brazers or brazing operators have been used.

PB-48.2 The Manufacturer shall make available to theInspector a certified copy of the record of the qualificationtests of each brazer and brazing operator. The Inspectorshall have the right at any time to call for and witness testsof the ability of a brazer or brazing operator.

PB-49 VISUAL EXAMINATIONPB-49.1 When possible, the Inspector shall visually

inspect both sides of each brazed joint after flux residueremoval. It is recognized that for certain joints (blind joints)this is not possible.

PB-49.2 When visually possible there shall be evidencethat the brazing filler metal has penetrated the joint. In abutt braze there shall be no concavity. The braze may berepaired or rebrazed.

PB-49.3 The presence of a crack in the brazing fillermetal shall be cause for rejection. Dye penetrant inspectionmay be used if desired. The braze may be repaired orrebrazed (see PB-33).

131

PB-49.4 The presence of a crack in the base metaladjacent to a braze shall be cause for rejection even if thecrack is filled with brazing alloy. Repair is not permitted.

PB-49.5 Pinholes or open defects in the braze shall because for rejection. The joint may be rebrazed.

PB-49.6 Rough fillets, particularly those with a convexappearance, are cause for rejection. Such joints may berepaired or rebrazed.

PB-50 EXEMPTIONS

Certain brazed joints regardless of their service tempera-tures may be exempt from the additional mechanical testingof this Section providing that the design application doesnot assume any benefit from the brazed joint strength. Itshall however meet the requirements of those qualificationtests required by Section IX of the Code (see PB-1.1,Scope).

MARKING AND REPORTS

PB-51 GENERAL

The provisions for marking and reports given in PG-104through PG-113 shall apply to brazed boilers and partsthereof.



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2010 SECTION I

PART PWTREQUIREMENTS FOR WATERTUBE BOILERS

GENERAL

PWT-1 GENERAL

The rules in Part PWT are applicable to watertube boilersand parts thereof and shall be used in conjunction with thegeneral requirements in Part PG as well as with the specialrequirements in the applicable Parts of this Section thatapply to the method of fabrication used. The rules in PartPWT do not apply to external piping.

MATERIALS

PWT-5 GENERALPWT-5.1 Materials used in the construction of pressure

parts for watertube boilers shall conform to one of thespecifications in Section II and shall be limited to thosefor which allowable stress values are given in Tables 1Aand 1B of Section II, Part D, for Section I construction or asotherwise specifically permitted in Part PG and Part PWT.

PWT-5.2 Mud drums of boilers shall be of eitherwrought steel or cast steel as designated in SA-216.

DESIGN

PWT-8 GENERAL

The rules in the following paragraphs apply specificallyto the design of watertube boilers and parts thereof andshall be used in conjunction with the general requirementsfor design in Part PG as well as with the specific require-ments for design in the applicable Parts of this Sectionthat apply to the method of fabrication used.

PWT-9 TUBES AND PIPEPWT-9.1 Economizer, boiler generator, and super-

heater tubes shall comply with the specifications as listedin PG-9.

PWT-9.2 Seamless steel pipe not exceeding NPS 11⁄2(DN 40) complying with SA-53 or SA-106 may bethreaded into the tubesheet, drum, or steel fitting of a

132

watertube boiler. Steel fittings, if used, must fully coverthe threads.

PWT-9.3 A tube in which a fusible plug is to beinstalled shall be not less than 0.22 in. (5.6 mm) in thicknessat the plug in order to secure four full threads for the plug(see also A-20).

PWT-11 TUBE CONNECTIONS

Tubes, pipe, and nipples may be attached to shells, heads,headers, and fittings by one of the following methods.

PWT-11.1 Tubes may be attached by expanding, flar-ing, beading, and seal welding in the following combina-tions illustrated in Fig. PWT-11:

(a) expanded and flared [illustration (a)](b) expanded and beaded [illustration (b)](c) expanded, flared, seal welded, and re-expanded after

welding [illustration (c)](d) expanded, seal welded, and re-expanded after weld-

ing or seal welded and expanded after welding [illustration(d)] or

(e) expanded only, in tubesheets having a thickness notless than 5⁄8 in. (16 mm), where the tube holes contain oneor more grooves, as shown in Fig. PWT-11. Tube holegrooves may have either a rounded or square profile.

The end of all tubes that are flared shall project throughthe tubesheet or header not less than 1⁄4 in. (6 mm) normore than 3⁄4 in. (19 mm) before flaring. Where tubes enterat an angle, the maximum limit of 3⁄4 in. (19 mm) shallapply only at the point of least projection. Tubes that areexpanded and flared without seal welding shall be flaredto an outside diameter of at least 1⁄8 in. (3.0 mm) greaterthan the diameter of the tube hole. For tubes that are sealwelded, the maximum throat of seal welds shall be 3⁄8 in.(10 mm). Tubes which are only expanded into groovedtube holes shall project through the tubesheet or headernot less than 1⁄8 in. (3 mm) but not more than 3⁄4 in. (19 mm).

PWT-11.2 Superheater, reheater, waterwall, or econo-mizer tubes may be welded to tubular manifolds, headers,or drums and tube ends or weld necks may be weldedto drums, all without expanding or flaring, provided theconnections comply with the requirements of PW-15 and



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2010 SECTION I

FIG. PWT-11 EXAMPLES OF ACCEPTABLE FORMS OF TUBE ATTACHMENT

1/16 in. (1.5 mm)

3/4 in. (19 mm) max.before flaring

3/8 in. (10 mm) max.

1/4 in. (6 mm) min.before flaring

(a) (b)

(d)(c)

3/8 in. (10 mm) max.

1/8 in. (3 mm) min.3/4 in. (19 mm) max.

Groove dimensions: 1/8 in. (3 mm) min. width 1/64 in. (0.5 mm) min. depthEdge to edge separation: 1/8 in. (3 mm) min. between grooves or between groove and tubesheet surface

(e)

PW-16. The welds shall be postweld heat treated whenrequired by PW-39.

PWT-11.3 Pipe used for tubes as provided in PWT-9.2may be attached by threading instead of expanding andflaring, provided the requirements in PG-39.5 are con-formed to.

PWT-11.4 Watertubes not exceeding 2 in. (50 mm)O.D. may be welded to tapered ferrules that are attachedto the drum by a driven interference fit. In addition to theinterference fit, the ferrules shall be held in place by retainerclamps attached to the drum with stud bolts. Welded studbolts shall comply with PW-27.2 and PW-28.6. Whentapped holes are provided for the studs, the stud bolts shall

133

comply with PG-39.4. The minimum cross-sectional areaof the remaining studs shall be determined by the followingequation, but shall not be less than that of a 3⁄8 in.(10 mm) stud.

A p 0.25�D2NP/S

where

A p the root area of the studD p the outside diameter of the ferrule at the inside

surface of the drumN p the number of fittings retained by the studP p the design pressureS p the allowable stress of the stud material at its

design temperature



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2010 SECTION I

FIG. PWT-12.1 BOX-TYPE HEADER JOINT

0.9 p max.

FIG. PWT-12.2 METHOD OF FORMINGWATERLEG JOINTS BY WELDING

4 in. (100 mm) max.

r

p/2

PWT-12 STAYBOLTING BOX-TYPE HEADERS

The front and back sheets of staybolted box-type headersmay be joined together by welding, provided

PWT-12.1 The flat portion in the trough of the headeras shown in Fig. PWT-12.1 does not exceed 90% of theallowable staybolt pitch permitted by PG-46, the weld isradiographed, and the welded structure is postweld heattreated or

PWT-12.2 The inside width of the waterleg does notexceed 4 in. (100 mm) (Fig. PWT-12.2), the distance fromthe weld to the nearest row of staybolts is not more than

(p /2 + r)

where

p p pitch permitted by PG-46r p radius of waterleg bottom curvature, in. [not to

exceed 2 in. (50 mm)]

134

The design pressure does not exceed 200 psi (1.5 MPa),the welded joint is not exposed to the products of combus-tion, and the welded structure is postweld heat treated.Volumetric examination is not required.

PWT-13 STAYING SEGMENT OF HEADS

The rules in PFT-25.2 shall be used to determine ifstaying is required.

PWT-14 FIRING DOORS

A watertube boiler shall have the firing doors of theinward-opening type, unless such doors are provided withsubstantial and effective latching or fastening devices orotherwise so constructed as to prevent them, when closed,from being blown open by pressure on the furnace side.

These latches or fastenings shall be of the positive self-locking type. Friction contacts, latches, or bolts actuatedby springs shall not be used. The foregoing requirementsfor latches or fastenings shall not apply to coal openingsof downdraft or similar furnaces.

All other doors, except explosion doors, not used in thefiring of the boiler may be provided with bolts or fasteningsin lieu of self-locking latching devices.

Explosion doors, if used and if located in the settingwalls within 7 ft (2.1 m) of the firing floor or operatingplatform, shall be provided with substantial deflectors todivert the blast.

PWT-15 ACCESS AND FIRING DOORS

The minimum size of an access or fire door opening, inwhich the minimum furnace dimension is 24 in. (600 mm),shall be not less than 12 in. � 16 in. (300 mm � 410 mm)or equivalent area, 11 in. (280 mm) to be the least dimen-sion in any case. A circular opening shall be not less than15 in. (380 mm) in diameter.

For furnace dimensions less than 24 in. (600 mm), theopening should be 23⁄4 in. � 31⁄2 in. (70 mm � 89 mm) orlarger where possible. In cases where the size or shape ofthe boiler prohibits an opening of that size, two openingswith a minimum size of 1 in. (25 mm) may be used,preferably oppposite each other, to permit inspection andcleaning of the furnace. If the burner is removable soas to permit inspection and cleaning through the burneropening, a separate access opening need not be provided.



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2010 SECTION I

PART PFTREQUIREMENTS FOR FIRETUBE BOILERS

GENERAL

PFT-1 GENERAL

The rules in Part PFT are applicable to firetube boilersand parts thereof and shall be used in conjunction with thegeneral requirements in Part PG as well as with the specificrequirements in the applicable Parts of this Section thatapply to the method of fabrication used.

MATERIALS

PFT-5 GENERALPFT-5.1 Materials used in the construction of pressure

parts for firetube boilers shall conform to one of the speci-fications given in Section II and shall be limited to thosefor which allowable stress values are given in Tables 1Aand 1B of Section II, Part D, or as otherwise specificallypermitted in Parts PG and PFT.

PFT-5.2 Waterleg and doorframe rings of vertical fire-tube boilers and of locomotive and other type boilers shallbe of wrought iron or steel or cast steel as designated inthe SA-216. The ogee or other flanged construction maybe used as a substitute in any case.

DESIGN

PFT-8 GENERAL

The rules in the following paragraphs apply specificallyto the design of firetube boilers and parts thereof and shallbe used in conjunction with the general requirements fordesign in Part PG as well as with the specific requirementsfor design in the applicable Parts of this Section that applyto the method of fabrication used.

PFT-9 THICKNESS REQUIREMENTSPFT-9.1 Shell and Dome. The thickness after forming

shall be as determined in accordance with the rules inPart PG.

PFT-9.2 TubesheetPFT-9.2.1 The thickness shall be as determined in

accordance with Part PG and Part PFT.

135

PFT-9.2.2 When buttwelded to the shell of a firetubeboiler, a formed tubesheet with a straight flange longerthan 11⁄2 times the tubesheet thickness shall have a straightflange thickness not less than 0.75 times the thickness ofthe shell to which it is attached.

PFT-10 SHELL JOINTS

Longitudinal and circumferential welded joints of a shellor drum shall comply with the rules in Part PW.

PFT-11 ATTACHMENT OF HEADS ANDTUBESHEETS

Flat heads and tubesheets of firetube boilers shall beattached by one of the following methods:

PFT-11.2 By flanging and butt welding in accordancewith Parts PG and PW.

PFT-11.3 By attaching an outwardly or inwardlyflanged tubesheet to the shell by fillet welding providedthe following requirements are met:

PFT-11.3.1 The tubesheet is supported by tubes, orstays, or both.

PFT-11.3.2 The joint attaching an outwardly flangedtubesheet is wholly within the shell and forms no partthereof.

PFT-11.3.3 Inwardly flanged tubesheets are full fil-let welded inside and outside.

PFT-11.3.4 The throat dimension of the full filletweld is equal to not less than 0.7 of the thickness ofthe head.

PFT-11.3.6 The construction conforms in all otherrespects to the requirements of this Section, including weld-ing and postweld heat treating, except that volumetricexamination is not required.

PFT-11.3.7 This construction shall not be used onthe rear head of a horizontal-return tubular boiler andinwardly flanged tubesheets shall not be used on a boilerwith an extended shell.

PFT-11.3.8 On inwardly flanged tubesheets, thelength of flange shall conform to the requirements of

(10)



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2010 SECTION I

PW-13 and the distance of the outside fillet weld to thepoint of tangency of the knuckle radius shall be not lessthan 1⁄4 in. (6 mm).

PFT-11.4 By attaching an unflanged tubesheet to theshell by welding, provided the requirements of PFT-11.4.1through PFT-11.4.7 are met

PFT-11.4.1 The tubesheet is supported by tubes, orstays, or both.

PFT-11.4.2 The welded joint may be made throughthe tubesheet or shell thickness. When the weld joint ismade through the shell, a minimum of 80% of the pressureload shall be carried by the tubes, stays, or both.

PFT-11.4.3 The weld is a full penetration weld equalat least to the full thickness of the base metal applied fromeither or both sides. When the full penetration weld ismade through the shell, an external fillet weld with a mini-mum throat of 1⁄4 in. (6 mm) shall be provided, and noweld prep machining shall be performed on the flat tube-sheet. The distance from the edge of the completed weldto the peripheral edge of the tubesheet shall not be lessthan the thickness of the tubesheet.

PFT-11.4.4 The shell or wrapper sheet, whereexposed to primary furnace gases1 and not water cooled,does not extend more than 1⁄8 in. (3 mm) beyond the outsideface of the tubesheet.

PFT-11.4.5 The weld attaching a furnace or a lowertubesheet of a vertical firetube boiler to the furnace sheetis wholly within the furnace sheet and is ground flush withthe upper or water side of the tubesheet.

PFT-11.4.6 The construction conforms in all otheraspects to the requirements of this Section including weld-ing, and postweld heat treatment, except that volumetricexamination is not required.

PFT-11.4.7 This construction shall not be used onthe rear head of a horizontal-return tubular boiler.

PFT-12 TUBESPFT-12.1 Allowable Working Pressure

PFT-12.1.1 The maximum allowable working pres-sure of tubes or flues of firetube boilers shall be as givenin PFT-50 and PFT-51.

PFT-12.1.2 The maximum allowable working pres-sure for copper tubes or nipples subjected to internal orexternal pressure shall not exceed 250 psi (1.7 MPa). Themaximum temperature shall not exceed 406°F (208°C).

The maximum allowable working pressure for copper-clad tubes subjected to external pressure shall be deter-mined by the formula in PFT-51, in which t may beincreased by one-half the thickness of the cladding.

1 Primary furnace gases are those in a zone where the design temperatureof those gases exceeds 850°F (455°C).

136

FIG. PFT-12.1 SOME ACCEPTABLE FORMS OFTUBE ATTACHMENT ON FIRETUBE BOILERS

(a)

(c)

(e)

(d)

(b)

t

T

T

(f)

t

(g) (h)

t

Note (1)Note (2)

Note (3)

Note (3) Note (4)

Accessible side for welding Tubesheet

WeldTube

NOTES:(1) Not less than t or 1⁄8 in. (3 mm), whichever is the greater, nor more

than 2t or 1⁄4 in. (6 mm), whichever is the lesser.(2) Not less than t or 1⁄8 in. (3 mm), whichever is the greater, nor more

than T/3 (see PFT-12.2.1.2).(3) Not more than t.(4) Not less than t or 1⁄8 in. (3 mm), whichever is the greater, nor more

than T/3 (see PFT-12.2.1.2).

PFT-12.2 Attachment of TubesPFT-12.2.1 Figure PFT-12.1 illustrates some of the

acceptable types of tube attachments. Such connectionsshall be

(a) expanded and beaded as in illustrations (a), (b),and (d)

(b) expanded and beaded and seal welded as in illustra-tion (c)

(c) expanded and seal welded as in illustration (e)(d) welded, as in illustrations (f) and (g)



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2010 SECTION I

Tube ends attached by expanding and welding are subjectto the provisions specified in PFT-12.2.1.1 through PFT-12.2.1.3.

PFT-12.2.1.1 Where no bevel or recess isemployed, the tube shall extend beyond the tubesheet notless than a distance equal to the tube thickness or 1⁄8 in.(3 mm), whichever is the greater, nor more than twice thetube thickness or 1⁄4 in. (6 mm), whichever is the lesser[see Fig. PFT-12.1, illustration (e)].

PFT-12.2.1.2 The tubesheet hole may be beveledor recessed. The depth of any bevel or recess shall not beless than the tube thickness or 1⁄8 in. (3 mm), whichever isgreater, nor more than one-third of the tubesheet thickness,except that when tube thicknesses are equal to or greaterthan 0.150 in. (4 mm), the bevel or recess may exceedT /3. Where the hole is beveled or recessed, the projectionof the tube beyond the tubesheet shall not exceed a distanceequal to the tube wall thickness [see Fig. PFT-12.1, illustra-tions (f) and (g)].

PFT-12.2.1.3 On types of welded attachmentshown in Fig. PFT-12.1, illustrations (c) and (e), the tubesshall be expanded before and after welding. On typesshown in illustrations (f) and (g), the tubes may beexpanded.

PFT-12.2.2 Expanding of tubes by the Prossermethod may be employed in combination with any beadedor seal welded attachment method [see Fig. PFT-12.1,illustration (b)].

PFT-12.2.3 After seal welding as shown by Fig.PFT-12.1, illustrations (c) and (e), a single hydrostatic testof the boiler shall suffice.

PFT-12.2.4 The inner surface of the tube hole inany form of attachment may be grooved or chamfered.

PFT-12.2.5 The sharp edges of tube holes shall betaken off on both sides of the plate with a file or other tool.

PFT-12.2.6 Welded tube attachments as shown byFig. PFT-12.1, illustration (h), may be made with partialor no insertion of the tube into the flat tubesheet. Thefollowing requirements shall be met for these attachments:

(a) The tube and tubesheet materials shall be restrictedto P-No. 1, P-No. 3, or P-No. 4 materials.

(b) The maximum design temperature at the weld jointshall not exceed 700°F (370°C).

(c) The weld shall be a full-penetration weld made fromthe I.D. of the tube. The throat of the weld shall be equalto or greater than the thickness of the tube. The root passshall be made using the GTAW process.

(d) PWHT per PW-39 is mandatory. The exemptionsto PWHT noted in Table PW-39 shall not apply.

(e) In addition to meeting the performance qualificationrequirements of Section IX, before making a productionweld each welder and welding operator shall demonstrate

137

his or her ability to achieve complete weld penetration andminimum thickness by successfully welding six test pieces.The test pieces shall be welded in a mockup of the produc-tion weld. The mockup shall be of identical position,dimensions, and materials as that of the production weld.The test pieces shall be visually examined to verify com-plete penetration and sectioned to verify minimum weldthickness. The results shall be recorded and maintainedwith the performance qualification record.

(f) Each weld surface on the tube I.D. shall receiveeither a magnetic particle or liquid penetrant examinationin accordance with A-260 or A-270 of Appendix A, asapplicable. In addition, a visual examination of the weldsurface on the tube O.D. shall be performed. The maximumpracticable number of these welds, but in no case fewerthan 50%, shall be visually examined. Visual examinationshall show complete penetration of the joint root and free-dom from cracks.

COMBUSTION CHAMBERS

PFT-13 COMBUSTION CHAMBERTUBESHEET

PFT-13.1 The maximum allowable working pressureon a tubesheet of a combustion chamber, where the crownsheet is not suspended from the shell of the boiler, shallbe determined by the following equation:


P p 27,000t(D − d)

WD

(SI Units)

P p 186t(D − d)

WD

where

D p least horizontal distance between tube centers ona horizontal row

d p inside diameter of tubesP p maximum allowable working pressuret p thickness of tubesheet

W p distance from the tubesheet to opposite combus-tion chamber sheet

Where tubes are staggered, the vertical distance betweenthe center lines of tubes in adjacent rows must not beless than

1 / 2 � 2dD + d2

Example: Required the maximum allowable workingpressure of a tubesheet supporting a crown sheet stayedby crown bars. Horizontal distance between centers, 41⁄8 in.;inside diameter of tubes, 2.782 in.; thickness of tubesheets



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2010 SECTION I

11⁄16 in.; distance from tubesheet to opposite combustion-chamber sheet, 341⁄4 in.; measured from outside of tubesheetto outside of back plate; material, steel. Substituting andsolving the following equation:

P p(4.125 − 2.782) � 0.6875 � 27,000

34.25 � 4.125p 176 psi

PFT-13.2 Sling stays may be used in place of girdersin all cases covered in PFT-13.1, provided, however, thatwhen such sling stays are used, girders or screw stays ofthe same sectional area shall be used for securing thebottom of the combustion chamber to the boiler shell.

PFT-13.3 When girders are dispensed with and the topand bottom of combustion chambers are secured by slingstays, the sectional area of such stays shall conform to therequirements of rules for stayed surfaces.

PFT-14 GENERALPFT-14.1 Furnaces may be constructed using seamless

pipe, electric resistance welded pipe within the limitationsof PG-9.5, or fusion welded plate of the double weldedbutt type. A sample of the longitudinal weld, made withthe addition of filler metal, of each section of a furnaceshall be subjected to a bend test in accordance with PW-53.No volumetric examination of the longitudinal or circum-ferential welds is required.

PFT-14.2 When the longitudinal joint will be subjectedto complete volumetric examination in accordance withPW-51 or PW-52, the individual bend test for each sectionof the furnace is not required.

PFT-15 PLAIN CIRCULAR FURNACESPFT-15.1 Plain circular furnaces may be made up to

any length, using sections where desired. The thicknessmay not be less than 5⁄16 in. (8 mm).

PFT-15.2 The maximum allowable working pressureshall be determined in accordance with PFT-51.

PFT-17 RING-REINFORCED TYPE

Horizontal cylindrical flues or furnaces (Fig. PFT-17.2)may be constructed with circular stiffening rings, providedthe requirements of PFT-17.1 through PFT-17.11.1 aremet.

PFT-17.1 The stiffening ring is rectangular in crosssection and is fabricated from one piece of plate, or fromplate sections or bars provided full penetration welds areused in assembling.

PFT-17.2 The stiffening ring after fabrication has athickness of not less than 5⁄16 in. (8 mm) and not more than

138

FIG. PFT-17.2 ACCEPTABLE TYPE OF RING-REINFORCED FURNACE

Alternate End Assemblies

Full penetration continuous weld both sides of rings

t

L

Do

Tr

Tr

Hr

Hr

L L

13⁄16 in. (21 mm) and in no case thicker than 11⁄4 times thefurnace wall thickness.

PFT-17.3 The ratio of the height of the stiffening ringto its thickness, Hr /Tr, is not greater than 8 nor less than 3.

PFT-17.4 The stiffening ring is attached to the furnaceby a full penetration weld on each side.

PFT-17.5 The thickness of the furnace wall or flue isa minimum of 5⁄16 in. (8 mm).

PFT-17.6 The spacing L of the rings on the furnace isnot greater than 60t or 36 in. (900 mm), whichever issmaller.

PFT-17.8 The boiler design permits replacement ofthe furnace. A flared or welded ogee ring is an acceptabletype of assembly.

PFT-17.10 The maximum allowable working pressureshall be determined in accordance with PFT-51.

PFT-17.11 The design of stiffening rings is determinedby the use of the symbols given in PFT-51, and the equationgiven in this paragraph.

PFT-17.11.1 The moment of inertia for a stiffeningring shall be determined by the following procedure.Step 1: Assuming that the furnace has been designed

and Do , Ls, and t are known, select a rectangularmember to be used for a stiffening ring anddetermine its area As and its moment of inertiaI. Then calculate B by the following equation:

B pPDo

t + (As /Ls)



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2010 SECTION I

where B p factor on the right-hand side of theapplicable chart in Section II, Part D.

Step 2: Enter the right-hand side of the chart at the valueof B determined in Step 1.

Step 3: Follow horizontally to the material line for thecorrect temperature.

Step 4: Move down vertically to the bottom of the chartand read the value of A.

Step 5: Compute the value of the required moment ofinertia Is by the following equation:

Is pDo

2Ls[ t + (As /Ls)]A14

Step 6: If the required Is is greater than the moment ofinertia I for the section selected in Step 1, selecta new section with a larger moment of inertiaand determine a new value of Is.

If the required Is is smaller than I for thesection selected in Step 1, that section should besatisfactory.

PFT-18 CORRUGATED FURNACESPFT-18.1 The maximum allowable working pressure

on corrugated furnaces, such as the Leeds suspension bulb,Morison, Fox, Purves, or Brown, having plain portions atthe ends not exceeding 9 in. (230 mm) in length (exceptflues especially provided for), when new and practicallycircular, shall be computed as follows:

P p Ct/D

where

C p 17,300 (119), a constant for Leeds furnaces, whencorrugations are not more than 8 in. (200 mm)from center to center and not less than 21⁄4 in.(57 mm) deep

p 15,600 (108), a constant for Morison furnaces,when corrugations are not more than 8 in.(200 mm) from center to center and not less than11⁄4 in. (32 mm) deep, and the radius of the outercorrugation r, is not more than one-half of theradius of the suspension curve R (see Fig. PFT-18.1)

p 14,000 (97), a constant for Fox furnaces, whencorrugations are not more than 8 in. (200 mm)from center to center and not less than 11⁄2 in.(38 mm) deep

p 14,000 (97), a constant for Purves furnaces, whenrib projections are not more than 9 in. (230 mm)from center to center and not less than 13⁄8 in.(35 mm) deep

p 14,000 (97), a constant for Brown furnaces, whencorrugations are not more than 9 in. (230 mm)

139

FIG. PFT-18.1 MORISON FURNACE

8 in. (200 mm) max.

r

R

CL

(r ≤ 1/2R)

11/4 in. (32 mm) min. depth suspension curve

from center to center and not less than 15⁄8 in.(41 mm) deep

D p mean diameterP p maximum allowable working pressuret p thickness, not less than 5⁄16 in. (8 mm) for Leeds,

Morison, Fox, and Brown, and not less than 7⁄16 in.(11 mm) for Purves furnaces

In calculating the mean diameter of the Morison furnace,the least inside diameter plus 2 in. (50 mm) may be takenas the mean diameter.

PFT-18.2 The thickness of a corrugated or ribbed fur-nace shall be ascertained by actual measurement by thefurnace manufacturer, by gaging the thickness of the corru-gated portions. For the Brown and Purves furnaces, themeasuring point shall be in the center of the second flat;for the Morison, Fox, and other similar types, in the centerof the top corrugation, at least as far in as the fourthcorrugation from the end of the furnace.

PFT-19 COMBINED PLAIN CIRCULAR ANDCORRUGATED TYPE

Combination type furnaces for external pressure may beconstructed by combining a plain circular section and acorrugated section provided

PFT-19.1 Each type of furnace is designed to be self-supporting, requiring no support from the other furnace attheir point of connection.

PFT-19.2 Paragraphs PFT-51 and PFT-15 are used forcalculating the maximum allowable working pressure ofthe plain section. In applying the length in the text, or Lin the formulas, the value used shall always be twice theactual length of the plain section. The actual length of theplain section is the distance measured from the center lineof the head attachment weld to the center line of the fullpenetration weld joining the two sections.



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FIG. PFT-19 CONNECTION BETWEEN PLAIN ANDCORRUGATED FURNACE

tc

Point of tangency

Max. 3tc or 11/2 in. (38 mm) (whichever is less)3

1

PFT-19.3 The maximum allowable working pressureof the corrugated section shall be determined from PFT-18.

PFT-19.4 The full penetration weld joining a plainself-supporting section to a corrugated self-supporting sec-tion shall be located as shown in Fig. PFT-19.

PFT-20 ATTACHMENT OF FURNACESPFT-20.2 Fillet Welded Construction. In a scotch

type boiler, a furnace may be attached to an outwardlyflanged opening in a front tubesheet by a circumferentialfillet weld, or a furnace may be attached to either tubesheetby flaring the end that extends beyond the outside face ofthe head to an angle of 20 deg to 30 deg, and using acircumferential fillet weld, provided the requirements ofPFT-20.2.1 through PFT-20.2.5 are met.

PFT-20.2.1 The area of the head around the furnaceis stayed by tubes, stays, or both in accordance with therequirements of this Section.

PFT-20.2.2 The joint is wholly outside the furnace.

PFT-20.2.3 The throat dimension of the full filletweld is not less than 0.7 times the thickness of the head.

PFT-20.2.4 Unless protected by refractory material,the furnace does not extend beyond the outside face ofthe tubesheet a distance greater than the thickness of thetubesheet. Any excess shall be removed before welding.

PFT-20.2.5 The construction conforms in all otherrespects to the requirements of this Section including weld-ing and postweld heat treating, except that volumetricexamination is not required.

PFT-20.3 Full Penetration Weld Construction. A fur-nace may be attached by a full penetration weld with thefurnace extending at least through the full thickness of thetubesheet but not beyond the toe of the weld, and the toeshall not project beyond the face of the tubesheet by morethan 3⁄8 in. (10 mm) unless protected from overheating byrefractory material or other means.

PFT-20.4 Throat Sheets. Throat sheets and inside andoutside front furnace sheets when fully stayed may beattached as required in PFT-11.4.

140

FIG. PFT-20 WELDING OGEE RING

1/2 Pitch (max.)

d (max.)d [max. = 4 in.

(100 mm)]

PFT-20.5 Furnace Sheets Attached by Welding. Ver-tical firetube boilers may be constructed by welding theogee bottom of the furnace sheet to the outside shell asshown in Fig. PFT-20, provided the requirements of PFT-20.5.1 through PFT-20.5.7 are met.

PFT-20.5.1 The tube or crown sheet is fully sup-ported by tubes, or stays, or both.

PFT-20.5.2 The joint is wholly within the shell andforms no part thereof.

PFT-20.5.3 The weld is not in contact with primaryfurnace gases.2

PFT-20.5.4 The throat dimension of the full filletweld is not less than 0.7 times the thickness of the fur-nace sheet.

PFT-20.5.5 The maximum depth of the waterlegdoes not exceed 4 in. (100 mm), and the radius of the ogeeis not greater than the inside width of the waterleg.

PFT-20.5.6 The pitch of the lower row of stayboltsmeets the requirements of PFT-27.5.

PFT-20.5.7 The construction conforms in all otherrespects to Code requirements including welding and post-weld heat treating, except that volumetric examination isnot required.

PFT-21 FIREBOXES AND WATERLEGSPFT-21.1 The width of waterlegs at the mudring in

vertical firetube and firebox boilers shall not exceed themaximum allowable pitch calculated using eq. (1) ofPG-46, using 2.1 or 2.2 for the value of C depending onthe plate thickness. The bottom edges of the plates forminga waterleg may be joined by flanging one or both platesas shown in Fig. PFT-21, illustrations (a) through (c).Similar construction details are acceptable, provided thepitch and waterleg width requirements are met.

PFT-21.2 As an alternative, the bottom edges of theplates forming a waterleg may be joined using a flat plate,or mudring, attached between the waterleg sides as shown

2 Primary furnace gases are those in a zone where the design temperatureof those gases exceeds 850°F (455°C).

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FIG. PFT-21 SOME ACCEPTABLE METHODS OF FORMING WATERLEG JOINTS BY WELDING

p max.

(a)

(c) (d) (e)

(b)

p/2 + rmax.

p max.

p/2 max.

p max.

p/2 + 2max.

p max.

rr

p/2 + 2max.

p max.

p/2 + 2max.

in Fig. PFT-21, illustrations (d) and (e). The required thick-ness of the mudring shall be calculated using eq. (1) ofPG-46, using 2.1 or 2.2 for the value of C, depending onthe plate thickness, and a value of p equal to the waterleginside width, but shall be not less than 1⁄2 in. (13 mm).

PFT-21.3 For waterlegs of vertical firetube boilers thatare attached to tubesheets or crownsheets, the unstayeddistance from a line of support on the tubesheet or crowns-heet provided by tubes or stays to the inside surface of theouter wall of the waterleg shall comply with the spacingrequirements of PFT-25.2 [see Fig. A-8, illustration (p)].

STAYED SURFACES

PFT-22 GENERAL

The rules of Parts PG and PW pertaining to stays andstayed surfaces that are applicable to firetube boilers shallbe used in conjunction with the following requirements.

141

PFT-23 WORKING PRESSURE FOR STAYEDCURVED SURFACES

PFT-23.1 The maximum allowable working pressurefor a stayed curved surface shall be the sum of the pressureas determined in PFT 23.1.1 and the lesser pressure deter-mined from either PFT-23.1.2 or PFT-23.1.3.

PFT-23.1.1 The maximum working pressure com-puted without allowing for the holding power of the stays,due allowance being made for the weakening effect of anyholes provided for construction.

PFT-23.1.2 The maximum working pressureobtained by the equation given in PG-46 using 1.3 for thevalue of C.

PFT-23.1.3 The maximum working pressureobtained by the following equation:

P1 pA1 SA2



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where

A1 p cross-sectional area of stayA2 p maximum area supported by stayP1 p pressure corresponding to the strength of the stayS p allowable stress of stay as given in Table 1A of

Section II, Part D

PFT-23.2 The maximum allowable working pressurefor a stayed wrapper sheet of a locomotive-type boiler shallbe the lesser of the value obtained in PFT-23.1 or the valueobtained in the following equation:

P pStE

R − �(s � sin a)

where

a p angle any crown stay makes with thevertical axis of boiler

E p minimum efficiency of wrapper sheetthrough joints or stay holes

P p maximum allowable working pressureR p radius of wrapper sheetS p allowable stress as given in Table 1A of

Section II, Part Ds p transverse spacing of crown stays in the

crown sheett p thickness of wrapper sheet

� (s � sin a) p summated value of transverse spacingfor all crown stays considered in onetransverse plane and on one side of thevertical axis of the boiler

The above equation applies to the longitudinal centersection of the wrapper sheet, and in cases where E isreduced at another section, the maximum allowable work-ing pressure based on the strength at that section may beincreased in the proportion that the distance from the wrap-per sheet to the top of the crown sheet at the center bearsto the distance measured on a radial line through the othersection, from the wrapper sheet to a line tangent to thecrown sheet and at right angles to the radial lines (see Fig.PFT-23.1).

PFT-23.3 Furnaces of Vertical Boilers. In a verticalfiretube boiler, the furnace length, for the purpose of calcu-lating its strength and spacing staybolts over its surface,shall be measured from the fire side face of flat tubesheetsor the point of tangency of flanged tubesheets to the insideof the lower mud ring.

PFT-23.3.1 A furnace for a vertical firetube boiler38 in. (970 mm) or less in outside diameter that requiresstaying shall have the furnace sheet supported by one ormore rows of staybolts, the circumferential pitch not toexceed 1.05 times that given by the equation in PG-46.

The longitudinal pitch between the staybolts shall notexceed that given by the following equation:

142

FIG. PFT-23.1 STAYED WRAPPER SHEET OFLOCOMOTIVE-TYPE BOILER

90 deg


L p �56,320t2

PR �2

(SI Units)

L p �77.05t2

PR �2

where

L p longitudinal pitch of stayboltsP p maximum allowable working pressureR p outside radius of furnacet p thickness of furnace sheet

When values by this formula are less than the circumferen-tial pitch, the longitudinal pitch may be as large as theallowable circumferential pitch.

The stress in the staybolts shall not exceed the allowablestress given in Table 1A of Section II, Part D, and deter-mined by PFT-26.1.

PFT-23.3.2 In furnaces over 38 in. (970 mm) inoutside diameter and combustion chambers not covered byspecial rules in this Section, which have curved sheetssubject to pressure on the convex side, neither the circum-ferential nor longitudinal pitches of the staybolts shallexceed 1.05 times that given by the rules in PG-46.

PFT-23.4 Upper combustion chambers of vertical sub-merged tubular boilers made in the shape of a frustrum ofa cone when not over 38 in. (970 mm) in outside diameterat the large end may be used without stays if computedby the rule for plain cylindrical furnaces in PFT-14, makingD in the formula equal to the outside diameter at the largeend, provided that the longitudinal joint conforms to therequirements of PFT-14.

PFT-23.5 For furnaces of PFT 23.4 when over 38 in.(970 mm) in outside diameter at the large end, that portionwhich is over 30 in. (760 mm) in diameter shall be fully



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FIG. PFT-25 EXAMPLE OF STAYING OF HEADSADJACENT TO CYLINDRICAL FURNACES

11/2 p

11/2 p11/2 p

11/2 p

11/2 p

supported by staybolts, and PFT-23.3.2 shall apply. Thetop row of staybolts shall be at a point where the cone topis 30 in. (760 mm) or less in diameter.

In calculating the pressure permissible on the unstayedportion of the cone, the vertical distance between the hori-zontal planes passing through the cone top and throughthe center of the top row of staybolts shall be taken as Lin PFT-51. Do in PFT-51 shall be taken as the inside diame-ter at the center of the top row of staybolts.

PFT-24 STAYING HORIZONTAL RETURNTUBE BOILERS

When stays are required, the portion of the heads belowthe tubes in a horizontal-return tubular boiler shall be sup-ported by through-stays attached by welding under PW-19or with nuts inside and outside at the front head and byattachments which distribute the stress at the rear head.

The distance in the clear between the bodies of the staysor of the inside stays where more than two are used shallnot be less than 10 in. (250 mm) at any point.

PFT-25 STAYING SEGMENTS OF HEADSPFT-25.1 A segment of a head shall be stayed by head-

to-head through stays or diagonal stays.

PFT-25.2 Stays shall be used in the tubesheets of afiretube boiler if the distance between the edges of thetube holes exceeds the maximum pitch of staybolts for thecorresponding plate thickness and pressure given in PG-46.

Any part of the tubesheet that comes between the tube,furnace, or water-cooled turnaround chamber, and the shellneed not be stayed if the greatest distance measured alonga radial line from the inner surface of the shell to the centerpoint of tangent to any two tube holes or tube hole andfurnace or water-cooled turnaround chamber on the shellside of such holes does not exceed 1.5 times the value ofp obtained by applying the formula of PG-46 with C equalto 1.8 or 1.9 depending upon the plate thickness. The tube

143

holes, or tube hole and furnace or water-cooled turnaroundchamber (see Fig. PFT-25), to which a common tangentmay be drawn in applying this rule, shall not be at agreater distance from edge to edge than the maximum pitchreferred to.

PFT-26 AREA SUPPORTED BY STAY

PFT-26.1 The full pitch dimensions of the stays shallbe employed in determining the area to be supported by astay, and the area occupied by the stay shall be deductedtherefrom to obtain the net area. The product of the netarea in square inches by the maximum allowable workingpressure in pounds per square inch gives the load to besupported by the stay.

PFT-26.2 Where stays come near the outer edge ofthe surfaces to be stayed and special allowances are madefor the spacing, the load to be carried by such stays shallbe determined by neglecting the added area provided forby these special allowances.

Example: If the maximum pitch by PG-46 would makea staybolt come 6 in. (150 mm) from the edge of theplate and a special allowance would make it come 7 in.(180 mm), the distance of 6 in. (150 mm) shall be used incomputing the load to be carried.

PFT-27 MAXIMUM SPACING

PFT-27.1 The maximum distance between the edgesof tube holes and the centers of stays shall be p as deter-mined by the formula in PG-46, using the value of C givenfor the thickness of plate and type of stay used.

PFT-27.2 For a flanged head welded to the shell, themaximum distance between the inner surface of the sup-porting flange and lines parallel to the surface of the shellpassing through the center of the stays shall be p as deter-mined by the formula in PG-46, plus the inside radius ofthe supporting flanges, using the C factor that applies to



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2010 SECTION I

the thickness of the head plate and type of stay used [seeFig. A-8, illustrations (i) and (j)].

PFT-27.3 For unflanged heads, the maximum distancebetween the inner surface of the shell and the centers ofstays shall not be more than one-half the maximum allow-able pitch as determined by PG-46, using 2.5 for the valueof C, plus 2 in. (50 mm) [see Fig. A-8, illustration (k)].

PFT-27.4 The pitch of diagonal stays attached by weld-ing between the shells and tubesheets of horizontal tubularand scotch boilers, and for other stays when the supportedplate is not exposed to radiant heat, as determined byPG-46, may be greater than 81⁄2 in. (216 mm), but shallnot exceed 15 times the stay diameter.

PFT-27.5 The pitch of the lower row of staybolts ofa vertical firetube boiler, which is required to be stayedby the rules in this Section, and which is fabricated bywelding the ogee bottom of the furnace sheet to the outsideshell, shall not exceed one-half the maximum allowablepitch as determined by PG-46, measured from the centerof the staybolt to the tangent of the ogee (see Fig. PFT-20).

PFT-27.6 The spacing of staybolts around door holesfabricated by fusion welding of the full penetration typeof two-flanged sheets, which are required to be stayed bythe rules of this Section (see Fig. PWT-12.2), shall notexceed one-half the maximum allowable pitch determinedby PG-46, measured from the center of the staybolt to thepoints of tangency of the flanges.

PFT-27.7 If the furnace sheets are required to be stayedby the rules of this Section, the spacing of staybolts arounddoor holes and the spacing of the first row of stayboltsfrom the bottom of a mud ring fabricated by fusion weldingof the full penetration type when either or both sheets arenot flanged [see Fig. A-8, illustrations (l) through (n)] shallnot exceed one-half the maximum pitch determined byPG-46, plus 2 in. (50 mm), measured from the center ofthe staybolt to the root of the weld.

PFT-27.8 The maximum distance from the first rowof stays to a full penetration weld in compression appliedfrom either or both sides of the tubesheet, attaching thecrown sheet of a furnace or combustion chamber to a stayedhead or tubesheet shall not exceed the pitch determinedby PG-46, measured from the center of the stay to thefurnace or combustion chamber side of the head or tube-sheet [see Fig. A-8, illustrations (o) and (p)].

PFT-27.9 When a flanged-in manhole opening with aflange depth of not less than three times the required thick-ness of the head, or when an unflanged manhole ring meet-ing the requirements of PG-32 through PG-39 is providedin a flat stayed head of a firetube boiler, as shown inFig. A-8, illustrations (q) and (r), the load created by theunsupported area of the manway shall be supported by the

144

FIG. PFT-27 PITCH OF STAYBOLTS ADJACENT TOUPPER CORNERS OF FIREBOXES

p

p

r

t

B

Max. r = p as calculated by PFT-27.11Min. r = 3 t

B

β

GENERAL NOTE: If the radius r exceeds the pitch, thecurved plate shall be stayed as a flat plate in accordancewith PG-46.

stays surrounding the manway. When the manway is inclose proximity to the shell, the load may be shared bythe shell by reducing the area supported by the stays by100 in.2 (64 500 mm2), provided the requirements of bothPFT-27.9.1 and PFT-27.9.2 are met.

PFT-27.9.1 The distance between the manhole open-ing and the inside of the shell does not exceed one-halfthe maximum allowable pitch for an unflanged manholeand one-half the maximum allowable pitch plus the radiusof the head flange for a flanged-in manhole in a flangedhead.

PFT-27.9.2 The distance between the centers of thefirst row of stays, or the edges of tube holes, and themanhole opening does not exceed one-half the maximumallowable pitch as determined by PG-46.

PFT-27.10 In applying these rules and those in PG-46to a head or plate having a manhole or reinforced opening,the spacing applies only to the plate around the openingand not across the opening.

PFT-27.11 For stays at the upper corners of fireboxes,the pitch from the staybolt next to the corner to the pointof tangency to the corner curve shall be (see Fig. PFT-27)

p p � 90Angularity of tangent lines (� )� � C t2S

P

where

C p factor for the thickness of plate and type of stayused as required in PG-46

P p maximum allowable working pressureS p maximum allowable stress value given in Table

1A of Section II, Part D



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2010 SECTION I

t p thickness of plate� p angle, deg

PFT-28 STAYBOLTS AND STAYSPFT-28.1 The required area at the point of least net

cross section of staybolts and stays shall be as given inPG-49. The maximum allowable stress per square inch atpoint of least net cross-sectional area of staybolts and staysshall be given as in Table 1A of Section II, Part D. Indetermining the net cross-sectional area of drilled or hollowstaybolts, the cross-sectional area of the hole shall bededucted.

PFT-28.2 The length of the stay between supports shallbe measured from the inner faces of the stayed plates. Thestresses are based on tension only. For computing stressesin diagonal stays, see PFT-32.

PFT-28.3 When stay rods are screwed through sheetsand riveted over, they shall be supported at intervals notto exceed 6 ft (1.8 m). Stay rods over 6 ft (1.8 mm) inlength may be used without support if fitted with nuts andwashers or attached by welding under PW-19, providedthe least cross-sectional area of the stay rod is not lessthan that of a circle 1 in. (25 mm) in diameter and therequirements of PG-46.8 are met.

PFT-29 FLEXIBLE STAYBOLTS

Flexible-type staybolts having a cover cap welded underthe provisions of PW-15 to the outer sheet may be usedin the construction of locomotive-type boilers, providedthe bolts are hollow-drilled from the threaded end into andpartly through the ball head to allow for proper inspection,and so that any breakage is disclosed by leakage at theinner end. These welded joints need not be postweld heattreated or volumetrically examined.

PFT-30 CROWN BARS AND GIRDER STAYSPFT-30.1 Crown bars and girder stays for tops of com-

bustion chambers and back connections, or wherever used,shall be proportioned to conform to the following equation:

P pCd2t

(W − p)D1W

where

C p 7,000 (48) when girder is fitted with one support-ing bolt

p 10,000 (69) when the girder is fitted with two orthree supporting bolts

p 11,000 (76) when the girder is fitted with four orfive supporting bolts

145

p 11,500 (79) when the girder is fitted with six orseven supporting bolts

p 12,000 (83) when the girder is fitted with eightor more supporting bolts

D1 p distance between girders from center to centerd p depth of girderP p maximum allowable working pressurep p pitch of supporting boltst p thickness of girder

W p extreme distance between supports of, in a scotchmarine boiler, the distance from the fire side ofthe tubesheet to the fire side of the back connec-tion plate

Example: Given Wp34 in., pp7.5 in., D1p7.75 in.,dp7.5 in., tp2 in.; three stays per girder, Cp 10,000;then substituting in the following equation:

P p10,000 � 7.5 � 7.5 � 2(34 − 7.5) � 7.75 � 34

p 161.1 psi

Sling stays, if used between crown bars and boiler shellor wrapper sheet, shall be proportioned so as to carrythe entire load without considering the strength of thecrown bars.

PFT-30.2 In a form of reinforcement for crown sheetswhere the top sheet of the firebox is a semicircle and thetop part of the circle not exceeding 120 deg in arc isreinforced by arch bars extending over the top and downbelow the top row of staybolts at the sides of the furnacebeneath the semicircular crown sheet, the maximum allow-able working pressure shall be determined by adding to themaximum allowable working pressure for a plain circularfurnace of the same thickness, diameter, and length deter-mined by the formula in PFT-51, the pressure P1 deter-mined from the following equation, which is a modificationof the formula in PFT-23:


P1 p 10,000,000bd3

D1 D3

(SI Units)

P1 p 69 000bd3

D1 D3

where

b p net width of crown barD p two times the radius of the crown sheet

D1 p longitudinal spacing of crown bar that shall notexceed twice the maximum allowable stayboltpitch

d p depth of crown bar

provided that the maximum allowable working pressuremust not exceed that determined by the equation for fur-naces of the ring-reinforced type, in PFT-51 when L is



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2010 SECTION I

made equal to D1, and also provided that the diameter ofthe holes for the staybolts in the crown bars does not exceed1⁄3b, and the cross-sectional areas of the crown bars is notless than 4 in.2 (2 580 mm2). PG-46 governs the spacingof the staybolts or bolts attaching the sheet to the bars,and PFT-28, the size of the staybolts or bolts.

For constructions in which the crown sheet is not semi-circular, or in which other features differ from those speci-fied above, a test shall be made in accordance with PG-100and the working pressure shall be based thereon.

PFT-30.3 Cast iron supporting lugs, legs, or ends shallnot be used.

PFT-31 STAY TUBESPFT-31.1 When tubes are used as stays in multitubular

boilers to give support to the tubesheets, the required cross-sectional area of such tubes shall be determined in accor-dance with PG-49.

PFT-31.2 The required tubesheet thickness and maxi-mum pitch of stay tubes shall be calculated using the fol-lowing equations:

t p � PCS �p2 −

�d 2

4 �p p � CSt2

P+

�d 2

4

where

C p 2.1 for tubesheets not over 7⁄16 in. (11 mm) thickp 2.2 for tubesheets over 7⁄16 in. (11 mm) thick

d p outside diameter of the tubeP p design pressurep p maximum pitch measured between the centers of

tubes in different rows, which may be horizontal,vertical, or inclined

S p maximum allowable stress value for the tube-sheet material given in Table 1A of Section II,Part D

t p required thickness of tubesheet

PFT-31.3 No calculation need be made to determinethe availability of the required cross-sectional area or themaximum allowable pitch for tubes within or on the perim-eter of a nest of tubes that are spaced at less than twicetheir average diameter.

PFT-31.4 Stay tubes may be attached by any of theacceptable means shown in Fig. PFT-12.1.

PFT-32 STRESSES IN DIAGONAL STAYSPFT-32.1 To determine the required area of a diagonal

stay, multiply the area of a direct stay required to support

146

FIG. PFT-32 MEASUREMENTS FOR DETERMININGSTRESSES IN DIAGONAL STAYS

l

L

the surface by the slant or diagonal length of the stay, anddivide this product by the length of a line drawn at rightangles to surface supported to center of palm of diagonalstay, as follows:

A p aL / l

where

A p sectional area of diagonal staya p sectional area of direct stayL p length of diagonal stay as indicated in Fig. PFT-32l p length of line drawn at right angles to boiler head

or surface supported to center of palm of diagonalstay, as indicated in Fig. PFT-32, in. (mm)

Example: Given diameter of direct stayp1 in., ap0.7854 in.2, Lp60 in., lp48 in.; substituting and solving

A p (0.7854 � 60) /48p 0.98 sectional area, in.2

Diameter(of diagonal stay) p ��0.9817 in.2 � 4��3.14�

p 1.118 in.2

Consequently, the next larger standard size of 11⁄8 in.diameter is selected.

PFT-32.2 For staying segments of tubesheets such asin horizontal-return tubular boilers, where L is not morethan 1.15 times l for any stay, the stays may be calculatedas direct stays allowing 90% of the allowable stress valuegiven in Table 1A of Section II, Part D.

DOORS AND OPENINGS

PFT-40 WELDED DOOR OPENINGS

Arc or gas welding may be used in the fabrication of doorholes provided the sheets are stayed around the opening inaccordance with the requirements of PFT-27.6 andPFT-27.7.

No calculations need be made to determine the availabil-ity of compensation for door openings spanning between

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2010 SECTION I

the plates of waterlegs. The required thickness of circularaccess openings shall be determined in accordance withPFT-51. The required thickness of door openings of otherthan circular shape shall be calculated using eq. (1) ofPG-46, using 2.1 or 2.2 for the value of C, depending onthe plate thickness, and a value of p equal to the waterleginside width. Volumetric examination of the joining weldsis not required.

PFT-41 OPENINGS IN WRAPPER SHEETS

Openings located in the curved portion of the wrappersheet of a locomotive type boiler shall be designed inaccordance with the rules in PG-32.

PFT-42 FIRESIDE ACCESS OPENINGS

The minimum size of an access or fire door opening, inwhich the minimum furnace dimension is 24 in. (600 mm),shall be not less than 12 in. � 16 in. (300 mm � 400 mm)or equivalent area, 11 in. (280 mm) to be the least dimen-sion in any case. A circular opening shall be not less than15 in. (380 mm) in diameter.

For furnace dimensions less than 24 in. (600 mm), theopening should be 23⁄4 in. � 31⁄2 in. (70 mm � 89 mm) orlarger where possible. In cases where the size or shape ofthe boiler prohibits an opening of that size, two openingswith a minimum size of 1 in. (25 mm) may be used,preferably oppposite each other, to permit inspection andcleaning of the furnace. If the burner is removable soas to permit inspection and cleaning through the burneropening, a separate access opening need not be provided.

The bonnet or smoke hood of a vertical flue or tubularboiler shall be provided with an access opening at least6 in. � 8 in. (150 mm � 200 mm) for the purpose ofinspection and cleaning the top head of the boiler.

PFT-43 REQUIREMENTS FOR INSPECTIONOPENINGS

All firetube boilers shall have sufficient inspection open-ings, handholes, or washout plugs with a minimum offour openings to permit inspection of the waterside of thetubesheets, furnaces, and tubes and to permit flushing ofloose scale and sediment from the boiler. Except wherespace restrictions would prohibit entry to the boiler, amanhole shall be provided in the upper portion of the shell.All openings shall meet the requirements of PG-32 throughPG-44. Where washout plugs are used, the minimum sizeshall be NPS 11⁄2 (DN 40), except for boilers 16 in.

147

(400 mm) or less in inside diameter, the minimum sizeshall be NPS 1 (DN 25).

PFT-44 OPENING BETWEEN BOILER ANDPRESSURE RELIEF VALVE

The opening or connection between the boiler and thepressure relief valve shall have at least the area of thevalve inlet.

After the boiler Manufacturer provides for the openingrequired by the Code, a bushing may be inserted in theopening in the shell to suit a pressure relief valve thatwill have the capacity to relieve all the steam that can begenerated in the boiler and which will meet the Coderequirements. The minimum size of the connection andopening for the pressure relief valve shall be not less thanNPS 1⁄2 (DN 15).

No valve of any description shall be placed between therequired pressure relief valve or valves and the boiler, oron the discharge pipe between the pressure relief valveand the atmosphere. When a discharge pipe is used, thecross-sectional area shall be not less than the full area ofthe valve outlet or of the total of the areas of the valveoutlets discharging thereinto and shall be as short andstraight as possible and so arranged as to avoid unduestresses on the valve or valves.

DOMES

PFT-45 REQUIREMENTS FOR DOMESPFT-45.1 The longitudinal joint of a dome may be

butt welded or the dome may be made without a seam ofone piece of steel pressed into shape. The dome flangemay be double full fillet lap-welded to the shell if allwelding complies fully with the requirements for weldingin Part PW. Volumetric examination of the fillet weldsmay be omitted. The opening shall be reinforced in accor-dance with PG-32 through PG-44.

PFT-45.3 When a dome is located on the barrel of alocomotive-type boiler or on the shell of a horizontal-returntubular boiler, the outside diameter of the dome shall notexceed six-tenths the inside diameter of the shell or barrelof the boiler unless the portion of the barrel or shell underthe dome (the neutral sheet) is stayed to the head or shellof the dome by stays which conform in spacing and sizeto the requirements given in PG-46. With such stayedconstruction the outside diameter of a dome located on thebarrel or shell of a boiler is limited to eight-tenths of thebarrel or shell inside diameter.

PFT-45.4 All domes shall be so arranged that any watercan drain back into the boiler.

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FIG. PFT-46.1 SPACING AND WELD DETAILS FOR WALL-SUPPORT LUGS SET IN PAIRSON HORIZONTAL-RETURN TUBULAR BOILERS

t

0.7t

2 in. (50 mm)

0.7t

t = not less than 1% of the boiler diameter

PFT-45.5 Flanges of domes shall be formed with acorner radius, measured on the inside, of at least twice thethickness of the plate for plates 1 in. (25 mm) in thicknessor less, and at least three times the thickness of the platefor plates over 1 in. (25 mm) in thickness.

PFT-45.6 In a locomotive-type boiler with a dome ona tapered course, the maximum allowable diameter of thedome shall be based on that diameter of the tapered coursewhich intersects the axis or center line of the dome.

SETTING

PFT-46 METHOD OF SUPPORTPFT-46.1 The design and attachment of lugs, hangers,

saddles, and other supports shall meet the requirements ofPG-22.1 and PG-55.

PFT-46.2 In applying the requirements of PFT-46.1,localized stresses due to concentrated support loads, tem-perature changes, and restraint against dilation of the boilerdue to pressure shall be provided for. Lugs, brackets, sad-dles, and pads shall conform satisfactorily to the shape ofthe shell or surface to which they are attached or withwhich they are in contact.

PFT-46.3 A horizontal-return tubular boiler over 72 in.(1 800 mm) in diameter shall be supported from steel hang-ers by the outside-suspension-type setting, independent ofthe furnace side walls.

PFT-46.4 A horizontal-return tubular boiler, 14 ft(4.3 m) or more in length, or over 54 in. (1 350 mm) and

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up to and including 72 in. (1 800 mm) in diameter, shallbe supported by the outside-suspension-type setting asspecified in PFT-46.3, or, for wall-supported boilers, atfour points by not less than eight steel lugs set in pairs. Ahorizontal-return tubular boiler up to and including 54 in.(1 350 mm) in diameter shall be supported by the outside-suspension-type setting as specified in PFT-46.3, or, forwall-supported boilers, by not less than two steel lugs oneach side. If more than four lugs are used on wall-supportedboilers, they shall be set in four pairs, the lugs of each pairto be spaced not over 2 in. (50 mm) apart and the load tobe equalized between them (see Fig. PFT-46.1). If theboiler is supported on structural steel work, the steel sup-porting members shall be so located that heat from thefurnace cannot impair their strength.

PFT-46.5 Figure PFT-46.2 illustrates an acceptabledesign of hanger bracket for welded attachment to weldedhorizontal-return tubular boilers with the additionalrequirement that the hanger pin be located at the verticalcenter line over the center of a welded contact surface.The bracket plates shall be spaced at least 21⁄2 in. (64 mm)apart, but this dimension shall be increased if necessaryto permit access for the welding operation.

PFT-46.6 Wet-bottom stationary boilers shall be sup-ported so as to have a minimum clearance of 12 in.(300 mm) between the underside of the wet-bottom andthe floor to facilitate inspection. Other types of firetubeboilers set horizontally shall be supported so that they havea minimum clearance of 12 in. (300 mm) between themetal surface of the shell and the floor. Boiler insulation,



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FIG. PFT-46.2 WELDED BRACKET CONNECTION FORHORIZONTAL-RETURN TUBULAR BOILERS

B

B

20 deg min.

20 deg min.

Dimension “R” not less than 11/2 × diameter of hole

21/2 in. (64 mm)min.

Dimension “T” not less than 1% of boiler diameter

“R”

“T”“T”

3/4 T3/4 T

3/4 T

Section B - B

saddles, or other supports shall be arranged so that inspec-tion openings are readily accessible.

PIPING, FITTINGS, AND APPLIANCES

PFT-47 WATER LEVEL INDICATORSPFT-47.1 Boilers of the horizontal firetube type that

exceed 16 in. (400 mm) in inside diameter shall be so setthat when the water is at the lowest visible level in thegage glass there shall be at least 3 in. (75 mm) abovethe lowest permissible water level as determined by theManufacturer.

Horizontal firetube boilers that do not exceed 16 in.(400 mm) in inside diameter shall have the lowest visiblelevel in the gage glass at least 1 in. (25 mm) above thelowest permissible water level as determined by the Manu-facturer.

PFT-47.2 Boilers of locomotives shall have at leastone gage glass provided with top and bottom shutoff cocksand lamp.

The lowest visible level in the gage glass shall be notless than 3 in. [75 mm] for boilers over 36 in. (900 mm)in inside diameter, nor less than 2 in. (50 mm) abovethe lowest permissible water level as determined by theManufacturer for boilers 36 in. (900 mm) or less but greaterthan 16 in. (400 mm) in inside diameter nor less than1 in. (25 mm) above the lowest permissible water-level asdetermined by the Manufacturer for boilers 16 in. (400 mm)or less in inside diameter. These are minimum dimensions,and on large locomotives and those operating on steep

149

grades, the height should be increased, if necessary, tocompensate for change of water level on descendinggrades.

The bottom mounting for the gage glass and for watercolumn if used must extend not less than 11⁄2 in. (38 mm)inside the boiler and beyond any obstacle immediatelyabove it, and the passage therein must be straight andhorizontal.

Tubular gage glasses shall be equipped with a protectingshield.

PFT-48 FEED PIPING

PFT-48.1 When a horizontal-return tubular boilerexceeds 40 in. (1 000 mm) in diameter, the feedwater shalldischarge at about three-fifths the length from the end ofthe boiler that is subjected to the hottest gases of the furnace(except a horizontal-return tubular boiler equipped with anauxiliary feedwater heating and circulating device), abovethe central rows of tubes. The feed pipe shall be carriedthrough the head or shell farthest from the point of dis-charge of the feedwater in the manner specified for a surfaceblowoff in PG-59.3.2, and be securely fastened inside theshell above the tubes.

PFT-48.2 In vertical tubular boilers the feedwater shallbe introduced at a point not less than 12 in. (300 mm)above the crown sheet. When the boiler is under pressure,feedwater shall not be introduced through the openings orconnections used for the water column or gage glass. Inclosed systems the water may be introduced through anyopening when the boiler is not under pressure.

PFT-49 BLOWOFF PIPING

PFT-49.1 Blowoff piping of firetube boilers that isexposed to products of combustion shall be attached byscrewing into a tapped opening with provisions for ascrewed fitting or valve at the other end.

PFT-49.2 Blowoff piping of firetube boilers which isnot exposed to products of combustion may be attachedby any method provided in this Section except byexpanding into grooved holes.

PFT-50 THICKNESS OF FURNACES ANDTUBES UNDER EXTERNALPRESSURE

PFT-50.1 Design Temperature shall be not less thanthe maximum expected mean wall temperature establishedby calculation or measurement. As an alternative to calcu-lating or measuring the maximum expected mean metal



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temperature, 700°F (370°C) may be used as the designtemperature.3

PFT-50.1.1 Temperatures in excess of the maximumtemperature listed for each material given in Tables 1Aand 1B of Section II, Part D, are not permitted.

PFT-50.1.2 Temperatures in excess of the maximumtemperature given on the external pressure charts are notpermitted.

PFT-50.1.3 Rounding off equation results to the nexthigher unit of 10 is permitted (see PG-27.4, Note 8).

PFT-51 MAXIMUM ALLOWABLE WORKINGPRESSURE

PFT-51.1 The maximum allowable working pressureof tubes, flues, plain circular, and ring reinforced furnacesof firetube boilers shall be as determined by the followingrules. External pressure charts for use in determination ofminimum requirements are given in Section II, Part D,Subpart 3. Figure numbers shown in this Article are con-tained in that Subpart.

PFT-51.1.1 The following symbols are used in theprocedures of this Article:

A p factor determined from Fig. G and used to enterthe applicable material chart in Section II, PartD. For the case of cylinders having Do /t valuesless than 10, see PFT-51.1.2(b).

AS p cross-sectional area of stiffening ringB p factor determined from the applicable material

chart in Section II, Part D, for maximum designmetal temperature

Do p outside diameter of cylindrical furnace or tubeE p modulus of elasticity of material at design temper-

ature. (For this value see the applicable materialschart in Section II, Part D. Interpolation may bemade between the lines for intermediate tempera-tures.)

IS p required moment of inertia of stiffening ring aboutits neutral axis parallel to the axis of the furnace

L p total length, of a furnace or tube between tube-sheets, or design length of a furnace taken as thelargest of the following:

(a) the greatest center-to-center distancebetween any two adjacent stiffening rings

(b) the distance between the tubesheet and thecenter of the first stiffening (ring reinforced)

(c) the distance from the center of the firststiffening ring to a circumferential line on a

3 The designer is cautioned that the actual maximum mean metaltemperature is dependent on the heat input to the furnace, the fuel type,and the design pressure. 700°F (370°C) may not be appropriate for higherdesign pressures resulting in furnaces over 1 in. (25 mm) thick, or forfurnaces with high heat inputs.

150

formed head at one-third the depth from the headtangent line

Ls p one-half of the distance from the center line ofthe stiffening ring to the next line of support onone side, plus one-half of the center line distanceto the next line of support on the other side ofthe stiffening ring, both measured parallel to theaxis of the cylinder. A line of support is

(a) a stiffening ring that meets the require-ments of PFT-17.11

(b) a circumferential connection to a tubesheetor jacket for a jacketed section of a cylindricalshell

(c) a circumferential line on a formed head atone-third the depth of the head from the headtangent line

P p external design pressurePa p calculated value of allowable external working

pressure for the assumed value of tS p the maximum allowable stress value at design

metal temperaturet p minimum required thickness of cylindrical fur-

naces or tubestS p nominal thickness of cylindrical furnace or tubes

PFT-51.1.2 Cylindrical Furnaces and Tubes. Therequired minimum thickness of a cylindrical furnance ortube under external pressure, either seamless or with longi-tudinal butt joints, shall be determined by the followingprocedure:

(a) cylinder having Do / t values equal to or greaterthan 10Step 1: Assume a value of t and determine the ratios

L /Do and Do /t.Step 2: Enter Fig. G of Section II, Part D, at the value

of L /Do determined in Step 1. For values of L /Do

greater than 50, enter the chart at a value ofL /Do p 50. For values of L /Do less than 0.05,enter the chart at a value of L /Do p 0.05.

Step 3: Move horizontally to the line for the value ofDo /t determined in Step 1. Interpolation may bemade for intermediate values of Do /t. From thispoint of intersection, move vertically downwardto determine the value of Factor A.

Step 4: Using the value of A calculated in Step 3, enterthe applicable material chart in Section II, Part D,for the material under consideration. Move verti-cally to an intersection with thematerial/temperature line for the design tempera-ture. Interpolation may be made between linesfor intermediate temperatures. In cases wherethe A value falls to the right of the end of thematerial temperature line, assume an intersectionwith the horizontal projection of the upper endof the material/temperature line. For values of



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2010 SECTION I

A falling to the left of the material/temperatureline, see Step 7.

Step 5: From the intersection obtained in Step 4, movehorizontally to the right and read the value ofFactor B.

Step 6: Using the value of B, calculate the value of themaximum allowable external pressure, Pa, usingthe following equation:

Pa p4B

3(Do /t)

Step 7: For values of A falling to the left of the applicablematerial /temperature line, the value of Pa shallbe calculated using the following equation:

Pa p2 AE

3(Do /t)

Step 8: Compare the calculated value of Pa obtained inStep 6 or 7 with P. If Pa is smaller than P,select a larger value for t and repeat the designprocedure until a value of Pa is obtained that isequal to or greater than P.

(b) cylinders having Do /t values of less than 10Step 1: Using the same procedure as given in (a) above,

obtain the value of B. For values of Do /t lessthan 4, the value of A shall be calculated usingthe following equation:

A p1.1

(Do /t )2

For values of A greater than 0.10, use a valueof 0.10.

Step 2: Using the value of B obtained in Step 1, calculatea value of Pa1 using the following equation:

151

Pa1 p �2.167Do /t

− 0.0833� B

Step 3: Calculate a value of Pa2 using the followingequation:

Pa2 p2SB

Do /t �1 −1

Do /t�where SB is the lesser of 2 times the maximumallowable stress values at design metal tempera-ture from Tables 1A and 1B of Section II, PartD; or, 1.8 times the yield strength of the materialat Design Metal Temperature from Table Y-1 ofSection II, Part D.

Step 4: The smaller of the values of Pa1 calculated inStep 2, or Pa2 calculated in Step 3 shall be usedfor the maximum allowable external pressure Pa.If Pa is smaller than P, select a larger value fort and repeat the design procedure until a value forPa is obtained that is equal to or greater than P.

PFT-51.1.3 The design pressure or maximum allow-able working pressure shall be not less than the maximumexpected difference in operating pressure that may existbetween the outside and the inside of the furnace or tubeat any time.

PFT-51.1.4 When necessary, furnaces shall be pro-vided with stiffeners or other additional means of supportto prevent overstress or large distortions under the externalloadings listed in PG-22 other than pressure and temper-ature.

PFT-52 FUSIBLE PLUGS

Hand-fired boilers shall be equipped with fusible plugsin accordance with the requirements of A-19 through A-21of Nonmandatory Appendix A.



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PART PFHOPTIONAL REQUIREMENTS FOR FEEDWATERHEATER (WHEN LOCATED WITHIN SCOPE OF

SECTION I RULES)

PFH-1

A feedwater heater is a heat exchanger in which feedwa-ter to be supplied to a boiler is heated by steam or waterextracted from the boiler or the prime mover. When sucha feedwater heater is located within the limit of Section Ipiping, as defined by PG-58.3, it falls within the scope ofSection I rules. With this arrangement, the feedwater heatermay be constructed in compliance with Section VIII, Divi-sion 1, subject to the following conditions.

PFH-1.1 The feedwater heater shall conform with Sec-tion VIII, Division 1 rules for unfired steam boilers[UW-2(c)].

PFH-1.2 The maximum allowable working pressureof the primary (feedwater) side of the heater shall be notless than the design pressure requirements of ASME B31.1,para. 122.1.3.

152

PFH-1.3 The design temperature of the tubes shall benot less than the saturated steam temperature correspondingto the maximum allowable working pressure of the shell.If the steam entering the shell side of the feedwater heateris superheated, the design temperature of the tubes in thedesuperheating zone shall be not less than the saturationtemperature corresponding to maximum allowable shellside working pressure plus 35°F (20°C).

PFH-1.4 The feedwater heater shall be stamped withthe ASME Code “U” symbol and be documented with theASME U-1 Data Form.

PFH-1.5 A nameplate per UG-119 shall be furnishedand shall show the additional information “and Part PFHof Section I.”

PFH-1.6 The Master Data Report for the completedboiler unit (see PG-113) shall indicate “Feedwater heaterconstructed to Section VIII, Division 1, as permitted byPart PFH.”



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PART PMBREQUIREMENTS FOR MINIATURE BOILERS

GENERAL

PMB-1 GENERAL

The rules in Part PMB are applicable to miniature boilersand parts thereof and shall be used in conjunction with thegeneral requirements in Part PG as well as with the specialrequirements in the applicable Parts of this Section thatapply to the method of fabrication used.

PMB-2 SCOPEPMB-2.1 The classification miniature boilers applies

to boilers that do not exceed the following limits:(a) 16 in. (400 mm) inside diameter of shell(b) 20 ft2 (1.9 m2) heating surface (not applicable to

electric boilers)(c) 5 ft3 (0.14 m3) gross volume,1 exclusive of casing

and insulation(d) 100 psig (700 kPa) maximum allowable working

pressure

PMB-2.2 If a boiler meets the miniature classification,the rules in this Part shall supplement the rules for powerboilers and take precedence over them when there is con-flict. Where any of the limits in PMB-2.1 are exceeded,the rules for power boilers shall apply.

MATERIALS

PMB-5 GENERALPMB-5.1 Unless specifically permitted elsewhere in

this Section, materials used in the construction of pressureparts for miniature boilers shall conform to one of thespecifications in Section II and shall be limited to thosefor which allowable stress values are given in Tables 1Aand 1B of Section II, Part D. Miscellaneous pressure partsshall conform to the requirements of PG-11.

1 This gross volume is intended to include such gas passages as areintegral with the assembled pressure parts and a definition is: the volumeof a rectangular or cylindrical enclosure into which all the pressure partsof the boiler in their final assembled positions could be fitted. Projectingnozzles or fittings need not be considered in the volume.

153

PMB-5.2 Seamless and welded shells made from pipefor miniature boilers shall be not less than 3⁄16 in. (5.0 mm)in thickness. Shells or heads made from plate shall be notless than 1⁄4 in. (6 mm) in thickness. Heads used as tube-sheets, with tubes expanded, shall be at least 5⁄16 in. (8 mm)in thickness.

PMB-5.3 Steam boiler parts of not over 600 in.3

(0.01 m3) in volume may be cast from copper alloy comply-ing with requirements of SB-61 or SB-62 of wall thicknessnot less than 1⁄4 in. (6 mm). Such steam boiler parts shallbe equipped with at least one brass washout plug of notless than 1⁄2 in. (13 mm) and shall be tested to a hydrostaticpressure of 600 psi (4 MPa).

PMB-5.4 Heads or parts of miniature boilers, whennot exposed to the direct action of the fire, may be madeof cast iron or malleable iron provided it complies with aspecification permitted in this Section.

PMB-5.5 Due to the small size of parts of miniatureboilers, the requirements of Identification, PG-77.1, neednot be met, provided the Manufacturer certifies on the DataReport accompanying the boiler that the material is inaccordance with the requirements of this Section. Provi-sions shall be made by the Manufacturer whereby he shallbe able to supply complete information regarding the mate-rial and details of construction of any boiler built underthe provisions of this Code.

DESIGN

PMB-8 GENERAL

The rules in the following paragraphs apply specificallyto the design of miniature boilers and parts thereof andshall be used in conjunction with the general requirementsfor design in Part PG as well as with the specific require-ments for design in the applicable Parts of this Sectionthat apply to the method of fabrication used.

PMB-9 WELDING

Miniature boilers may be constructed by fusion weldingin accordance with all the requirements of this Section

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2010 SECTION I

except that postweld heat treatment, volumetric examina-tion of the welded joints, and nondestructive examinationsdescribed in PG-93.1 are not required.

PMB-10 WASHOUT OPENINGSPMB-10.1 Every miniature boiler exceeding 12 in.

(300 mm) internal diameter or having more than 10 ft2

(0.9 m2) of heating surface shall be fitted with not lessthan three brass washout plugs of 1 in. (25 mm), whichshall be screwed into openings in the shell near the bottom.Boilers not exceeding 12 in. (300 mm) internal diameterand having less than 10 ft2 (0.9 m2) of heating surfaceneed have not more than two 1 in. (25 mm) openings forcleanouts, one of which may be used for the attachmentof the blowoff valve; these openings shall be opposite toeach other where possible. All threaded openings in theboiler shall be provided with a welded reinforcement, ifnecessary, to give four full threads therein.

PMB-10.2 Miniature boilers of a design employing aremovable top cover flange for inspection and cleaningneed not be fitted with washout openings.

PMB-11 FEEDWATER SUPPLYPMB-11.1 Every miniature boiler shall be provided

with at least one feed pump or other feeding device, exceptwhere it is connected to a water main carrying sufficientpressure to feed the boiler or where it is operated with noextraction of steam (such as in a closed system). In thelatter case, in lieu of a feeding device, a suitable connectionor opening shall be provided to fill the boiler when cold.Feedwater openings or connections to miniature boilersshall be not less than NPS 1⁄2 (DN 15) for iron or steel pipeand NPS 1⁄4 (DN 8) for brass or copper pipe.

PMB-11.2 The feed pipe shall be provided with a checkvalve and a stop valve of a size not less than that of thepipe. The feedwater may be delivered through the blowoffopening if desired.

PMB-12 BLOWOFF

Each miniature boiler shall be equipped with a blowoffconnection, not less than NPS 1⁄2 (DN 15), located to drainfrom the lowest water space practicable. The blowoff shallbe equipped with a valve or cock not less than NPS 1⁄2(DN 15).

PMB-13 WATER GAGESPMB-13.1 Each miniature boiler for operation with a

definite water level shall be equipped with a water gage

154

glass for determining the water level. The lowest permissi-ble water level of vertical boilers shall be at a point one-third of the height of the shell above the bottom head ortubesheet. Where the boiler is equipped with an internalfurnace, the lowest permissible water level shall be notless than one-third of the length of the tubes above the topof the furnace tubesheet. In the case of small boilers oper-ated in a closed system where there is insufficient spacefor the usual water gage glass, water level indicators ofthe glass bull’s-eye type may be used.

PMB-13.2 Miniature boilers shall have the lowest visi-ble part of the water gage located at least 1 in. (25 mm)above the lowest permissible water level specified by theManufacturer.

PMB-14 FIXTURES AND FITTINGS

All valves, pipe fittings, and appliances connected to aminiature boiler shall be equal at least to the requirementsof Class 125 (PN 20) or Class 150 (PN 20) of the appro-priate ASME Standard listed in PG-42.

PMB-15 PRESSURE RELIEF VALVESPMB-15.1 Each miniature boiler shall be equipped

with a sealed pressure relief valve of not less than NPS 1⁄2(DN 15).

PMB-15.2 The minimum relieving capacity of thepressure relief valve shall be determined in accordancewith PG-67.2.

PMB-15.3 All other provisions for pressure reliefvalves in this Section shall be complied with.

PMB-16 STEAM STOP VALVES

Each steam line from a miniature boiler shall be providedwith a stop valve located as close to the boiler shell ordrum as is practicable, except when the boiler and steamreceiver are operated as a closed system.

PMB-17 AUTOMATIC DEVICES

All miniature boilers operated with gas, electricity, oil,or mechanical firing shall be provided with an automaticlow-water fuel cutoff, except electric boilers of the elec-trode type as provided for in PEB-16.

PMB-21 HYDROSTATIC TESTS ANDINSPECTION

PMB-21.1 In addition to the inspections required else-where in this Section, each miniature boiler pressure vessel



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2010 SECTION I

shall be inspected while being tested at a hydrostatic pres-sure equal to three times the maximum allowable workingpressure.

PMB-21.1.1 A minimum metal temperature of 60°F(15°C) is permitted during the hydrostatic test inPMB-21.1, provided the shell thickness is 3⁄8 in. (10 mm)or less and provided only P-No. 8 or the following specificP-No. 1 materials are used in the construction of the pres-sure vessel:

SA-53 Pipe Grade E or SSA-106 PipeSA-516 Plate

155

SA-105 ForgingsSA-234 Fittings

PMB-21.2 Completed miniature boilers with mechani-cally assembled boiler external piping (BEP) and trim shallbe given a final hydrostatic test at a pressure not less than11⁄2 times the MAWP of the pressure vessel. Miniatureelectric boilers shall be given a final hydrostatic test inaccordance with PEB-17.2

PMB-21.3 For completed miniature boilers withwelded or brazed boiler external piping (BEP) or trim, theinspection requirements of PG-90.1 and the hydrostatictest requirements of PG-99 apply.



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2010 SECTION I

PART PEBREQUIREMENTS FOR ELECTRIC BOILERS

GENERAL

PEB-1 GENERAL

The rules in Part PEB are applicable to electric boilersand parts thereof and shall be used in conjunction with thegeneral requirements in Part PG as well as with the specialrequirements in the applicable Parts of this Section thatapply to the method of fabrication used.

PEB-2 SCOPEPEB-2.1 This Part contains special rules for construc-

tion of electric boilers, both of the electrode and immersionresistance element type. This Part does not include electricboilers where the heat is applied externally to the boilerpressure vessel by electric resistance heating elements,induction coils, or other electrical means. These types ofelectric boilers shall be constructed in accordance withother applicable Parts of this Section.

PEB-2.2 Electric boilers and parts thereof that do notexceed the diameter, volume, or pressure limits of PMB-2may be constructed using the applicable paragraphs of PartPMB in conjunction with this Part.

PEB-2.3 An electrode type boiler is defined as an elec-tric boiler in which heat is generated by the passage of anelectric current using water as the conductor.

PEB-2.4 An immersion resistance element type boileris defined as an electric boiler in which heat is generatedby the passage of an electric current through a resistanceheating element directly immersed in water, or enclosedin a pipe immersed in water.

PEB-2.5 Electric boilers may be field assembled pro-vided the boiler is manufactured and assembled in compli-ance with the provisions and requirements of Part PEBand other applicable Parts of this Section.

PEB-3 OPTIONAL REQUIREMENTS FORTHE BOILER PRESSURE VESSEL

The boiler pressure vessel may be constructed in compli-ance with the ASME Pressure Vessel Code Section VIII,

156

Division 1, rules for unfired steam boilers [UW-2(c)] sub-ject to the conditions specified in PEB-3.1 through PEB-3.4.

PEB-3.1 The Manufacturer who certifies and stampsthe completed boiler shall specify to the “U” stamp holderall additional requirements of Part PEB, which are notrequirements of Section VIII, Division 1, and shall ensurethat these requirements are satisfied.

PEB-3.2 These additional requirements are

PEB-3.2.1 The materials of construction shall com-ply with the requirements of PEB-5.1 and PEB-5.3.

PEB-3.2.2 Inspection openings shall comply withthe requirements of PEB-10.

PEB-3.3 The boiler pressure vessel shall be stampedwith the ASME Code “U” symbol and the letters “UB,”and be documented with the ASME U-1 or U-1A DataReport.

PEB-3.4 The master Data Report P-2A for the ElectricBoiler shall indicate “Boiler pressure vessel constructed toSection VIII, Division 1 as permitted by Part PEB.”

MATERIALS

PEB-5 GENERALPEB-5.1 Unless specifically permitted elsewhere in this

section, materials used in the construction of pressure partsfor electric boilers shall conform to one of the specificationsin Section II and shall be limited to those permitted byPG-6, PG-7, PG-8, and PG-9 for which allowable stressvalues are given in Tables 1A and 1B of Section II, PartD. Miscellaneous pressure parts shall conform to therequirements of PG-11.

PEB-5.2 Seamless or welded shells, plates, or headsof electric boilers shall not be less than 3⁄16 in. (5 mm) inthickness.

PEB-5.3 Electric boilers of the immersion element typemay be fabricated of austenitic stainless steel type 304,304L, 316, 316L, and 347 of any material specificationlisted in PG-6 and PG-9, provided that a precautionary



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(10)

2010 SECTION I

statement indicating that the boiler shall be operated usingonly deionized water, having a maximum conductance of1 microSiemen per cm (1 �S/cm) [minimum specificresistivity of 1 megohm per cm (1 MΩ/cm)], is clearlymarked on the boiler in a visible location.

DESIGN

PEB-8 GENERALPEB-8.1 The rules in the following paragraphs apply

specifically to the design of electric boilers and partsthereof. They shall be used in conjunction with the generalrequirements for design in Part PG, any applicable require-ments in Part PMB for miniature boilers, and with thespecific requirements for design in applicable Parts of thisSection that apply to the method of fabrication used.

PEB-8.2 Responsibility of design of electric boilers tobe marked with the “E” symbol shall be that of the holderof the “E” stamp.

PEB-9 WELDING

Electric boilers may be constructed by fusion weldingin accordance with all the requirements of this Sectionexcept that postweld heat treatment, volumetric examina-tion of the welded joints, and the nondestructive examina-tions described in PG-93.1 are not required when thelimitations in PMB-2.1 are not exceeded.

PEB-10 INSPECTION OPENINGSPEB-10.1 Electric boilers of a design employing a

removable cover, or removable internal electric heatingelements that will permit access for inspection, and clean-ing and having an internal volume (exclusive of casingand insulation) of not more than 5 ft3 (0.14 m3) need notbe fitted with washout or inspection openings.

PEB-10.2 Electric boilers of more than 5 ft3 (0.14 m3)not provided with a manhole, shall have an inspectionopening or handhole located in the lower portion of theshell or head. The inspection opening shall not be smallerthan NPS 3 (DN 80). In addition, electric boilers of theresistance heating element type designed for steam serviceshall have an inspection opening or handhole at or nearthe normal waterline.

PEB-11 FEEDWATER SUPPLYPEB-11.1 The feedwater source to electric boilers shall

be capable of meeting the applicable requirements ofPG-61. Feedwater connections to an electric boiler shall

157

not be smaller than NPS 1⁄2 (DN 15), except as permittedby PMB-11.

PEB-11.2 Electric boilers that do not exceed the diame-ter, volume, or pressure limits of PMB-2, may have thefeedwater delivered through the blowoff opening if desired.

PEB-12 BLOWOFFPEB-12.1 The blowoff piping for each electric boiler

pressure vessel having a normal water content notexceeding 100 gal (380 L) is required to extend throughonly one valve.

PEB-12.2 The minimum size of blowoff pipes andfittings shall be NPS 1 (DN 25), except that for boilers of200 kW input or less the minimum size of pipe and fittingsmay be NPS 3⁄4 (DN 20). Electric boilers that do not exceedthe diameter, volume, or pressure limits of PMB-2 mayhave blowoff connections in accordance with PMB-12.

PEB-13 WATER LEVEL INDICATORSPEB-13.1 Electric boilers of the electrode type shall

have at least one gage glass. The gage glass shall be locatedas to indicate the water levels both at startup and undermaximum steam load conditions as established by the Man-ufacturer.

PEB-13.2 Electric boilers of the resistance elementtype shall have at least one gage glass. The lowest visiblewater level in the gage glass shall be at least 1 in. (25 mm)above the lowest permissible water level as determined bythe Manufacturer. Each electric boiler of this type shallalso be equipped with an automatic low-water cutoff oneach boiler pressure vessel so located as to automaticallycut off the power supply to the heating elements beforethe surface of the water falls below the visible level in thegage glass.

PEB-13.3 Tubular gage glasses on electric boilers shallbe equipped with protective rods or shields.

PEB-14 PRESSURE GAGES

Pressure gages shall meet the requirements of PG-60.6.

PEB-15 PRESSURE RELIEF VALVESPEB-15.1 Each electric boiler shall have at least one

pressure relief valve. Electric boilers with a power inputmore than 1,100 kW shall have two or more pressure reliefvalves.

PEB-15.2 The minimum pressure relief valve relievingcapacity for electric boilers shall be 31⁄2 lb /hr /kW



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2010 SECTION I

(1.6 kg/hr/kW) input. The pressure setting shall be nothigher than the MAWP stamped on the completed boiler(see PEB-18.3.2).

PEB-15.3 Pressure relief valves shall be mounted inaccordance with PG-71.2 with the spindle vertical. Electricboilers that do not exceed the diameter, volume, or pressurelimits of PMB-2, may have a pressure relief valve(s)installed in other than the vertical position, provided that

(a) the valve design is satisfactory for such position(b) the valve is not larger than NPS 3⁄4 (DN 20)(c) the maximum angle of deviation from vertical does

not exceed 30 deg(d) the nozzle location is such that no material that could

interfere with the operation of the valve can accumulateat the valve inlet

(e) the discharge opening of the valve body and dis-charge piping is oriented so that drainage is adequate

PEB-16 AUTOMATIC DEVICES

Electric boilers shall be provided with pressure and/ortemperature controls and an automatic low-water fuel cut-off. No low-water cutoff is required for electrode typeboilers.

PEB-17 HYDROSTATIC TESTPEB-17.1 Each electric boiler pressure vessel shall

be hydrostatically tested at completion of fabrication inaccordance with PG-99 or PMB-21, as applicable.

PEB-17.2 In addition to the above, after assembly ofthe boiler pressure vessel and the mechanically assembledboiler external piping and trim, the completed electricboiler shall be given a final hydrostatic test at a pressurenot less than the pressure relief valve setting.

PEB-17.3 When the electric boiler is to be markedwith the “E” symbol, the symbol shall be applied aftercompletion of the hydrostatic test of PEB-17.2.

PEB-18 INSPECTION AND STAMPINGOF BOILERS

PEB-18.1 Inspection of electric boilers shall be asrequired by PG-90.1 and PG-90.3. Witness by the Author-ized Inspector of the hydrotest required in PEB-17.2 forthe completed boiler may be omitted for electric boilersthat meet all the following limitations:

(a) 800 kW maximum per vessel(b) 600 V maximum(c) mechanically assembled boiler external piping

(BEP) onlyWhen the Authorized Inspector does not perform a final

inspection of the completed boiler, the Manufacturer or

158

Assembler shall make an equivalent examination. Theequivalent examination shall be in accordance with a qual-ity control procedure meeting the requirements ofPEB-18.2 and PEB-18.5.

PEB-18.1.1 Electric boilers exceeding the size limi-tations specified in PEB-18.1, and having only mechani-cally assembled external piping (BEP) and trim, shall havea final inspection by the Authorized Inspector, who shallalso witness the hydrostatic test called for in PEB-17.2.

PEB-18.1.2 For electric boilers having welded orbrazed boiler external piping (BEP) or trim, the inspectionrequirements of PG-90.1 and the hydrostatic test require-ments of PG-99 apply.

PEB-18.2 Each electric boiler Manufacturer shall com-ply with the applicable requirements of PG-104 andPG-105.

PEB-18.2.1 An electric boiler Manufacturer orAssembler applying for or renewing the “E” stamp shallhave its facilities and organizations subject to a joint reviewby its Authorized Inspection Agency and the legal jurisdic-tion involved (see last paragraph of PG-105.4).

PEB-18.2.2 A Manufacturer or Assembler assem-bling units where the final shop inspection by the Author-ized Inspector is not mandatory (see PEB-18.1), shall besubject to periodic review by its Authorized InspectionAgency. The review shall be conducted on a quarterly basisor more frequently if deemed necessary by the AuthorizedInspection Agency. The frequency of this review may bereduced subject to written agreement between the Manufac-turer or Assembler and its inspection agency and the writtenapproval of the appropriate legal jurisdiction. However, inno case shall the review be less than once every 6 months.

PEB-18.3 The stamping of electric boilers shall con-form to the requirements of PG-106. Completed electricboilers shall be marked with the “S” or “M” symbol bythe Manufacturer of the boiler pressure vessel except whenthe boiler pressure vessel is constructed under the provi-sions of PEB-3 (see PEB-18.4). When the trim, fixturesand fittings (such as valves), threaded boiler external pip-ing, and appurtenances are connected to an electric boilerby a Manufacturer or Assembler not authorized to applythe “S” or “M” stamp, the boiler assembler shall apply an“E” stamp to the completed assembly. “E” stamp holdersare limited to the use of assembly methods that do notrequire welding or brazing.

PEB-18.3.1 The stamping of the boiler pressure ves-sel shall be located as called for in PG-111.8 and need notindicate the kW input or the maximum designed steamingcapacity.

PEB-18.3.2 The stamping of the complete electricboiler shall be on a separate metallic plate and shall bein accordance with PG-106.4. The MAWP shall be that



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2010 SECTION I

established by the completed boiler assembler holding the“S,” “M,” or “E” stamp, but in no case higher than theMAWP stamped on the boiler shell. The MAWP shall belisted on Part II of Form P-2A, Manufacturers’ Data Reportfor All Types of Electric Boilers. This plate shall be locatedon the assembly so that it is readily visible from theoperating floor.

PEB-18.3.3 The stamping required by PEB-18.3.2need not be done in the presence of the Authorized Inspec-tor for electric boilers that do not receive final inspectionby the Authorized Inspector (see PEB-18.1).

PEB-18.4 For boiler pressure vessels constructed underthe provisions of PEB-3, the inspection and stampingrequirements of Section VIII, Division 1, UG-116(c) forspecial service pressure vessels (UB), shall be followed.

PEB-18.5 Those Manufacturers and Assemblers pro-viding an equivalent examination of completed electricboilers when final inspection is not witnessed by theAuthorized Inspector (see PEB-18.1), shall provide over-sight by a Certified Individual (CI).

PEB-18.5.1 A Certified Individual (CI) shall be anemployee of the Manufacturer or Assembler and shall bequalified and certified by the Manufacturer or Assembler.Qualifications shall include as a minimum

(a) knowledge of the requirements of this Section forthe application of Code symbols

(b) knowledge of the Manufacturer’s quality program(c) training commensurate with the scope, complexity,

or special nature of the activities to which oversight is tobe provided

159

The Manufacturer or Assembler shall maintain a recordcontaining objective evidence of the Certified Individual’squalifications, training, and certification.

PEB-18.5.2 The duties of a Certified Individual (CI)shall be to assure that each use of the Code symbol aspermitted in PEB-18.3.3 is in accordance with the require-ments of this Section and is documented on the Certificateof Conformance on Form P-2A, Manufacturers’ DataReport for All Types of Electric Boilers. The CI shall also

(a) verify that each electric boiler, to which a Codesymbol is applied, meets all applicable requirements ofthis Section

(b) sign the Certificate of Conformance, Form P-2A,prior to release of control of the boiler

PEB-19 MANUFACTURER’S DATA REPORTFOR ELECTRIC BOILERS

PEB-19.1 This form consists of two parts. Part I is tobe completed by the Manufacturer of the boiler pressurevessel who is the holder of the “S” or “M” stamp andhis inspection agency. Part II is to be completed by theManufacturer or Assembler responsible for the completedelectric boiler who shall be authorized to use any of the“S,” “M,” or “E” stamps.

PEB-19.2 When the boiler pressure vessel is con-structed by a “U” stamp holder and certified on a U-1 orU-1A Data Report, Part 1 shall be completed by the “S,”“M,” or “E” stamp holder to the extent indicated in GuideA-351.1.



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2010 SECTION I

PART PVGREQUIREMENTS FOR ORGANIC FLUID

VAPORIZERS

GENERAL

PVG-1 GENERAL

The rules in Part PVG are applicable to organic fluidvaporizers and parts thereof and shall be used in conjunc-tion with the general requirements in Part PG as well aswith the special requirements in the applicable Parts ofthis Section that apply to the method of fabrication used.

MATERIALS

PVG-5 GENERALPVG-5.1 Materials used in the construction of pressure

parts for organic fluid vaporizers shall conform to one ofthe specifications in Section II and shall be limited to thosefor which allowable stress values are given in Tables 1Aand 1B of Section II, Part D. Pressure relief valve materialsshall conform to PG-73.2.3.

PVG-5.2 The requirements for materials given in PartPG shall apply in all respects to organic fluid vaporizers.

DESIGN

PVG-8 GENERAL

The rules in the following paragraphs apply specificallyto the design of organic fluid vaporizers and parts thereofand shall be used in conjunction with the general require-ments for design in Part PG as well as with the specificrequirements for design in the applicable Parts of this Sec-tion that apply to the method of fabrication used.

PVG-9 GENERAL REQUIREMENTS

The Manufacturer shall be responsible for providing inthe design the limited heat absorption rates, proper furnaceproportions, etc., which will permit satisfactory and safeoperation of the vaporizers under all conditions of oper-ation.

160

PVG-10 GAGE GLASSES

Gage glasses shall be of the flat glass type with forgedsteel frames. Gage cocks shall not be used.

PVG-11 DRAIN VALVES

Suitable drain valves of the globe or angle type may beused in lieu of the blowoff valve required in ASME B31.1.

PVG-12 PRESSURE RELIEF VALVESPVG-12.1 Pressure relief valves shall be of a totally

enclosed type so designed that vapors escaping beyond thevalve seat shall not discharge into the atmosphere, exceptthrough an escape pipe that will carry such vapors to asafe point of discharge outside of the building. A suitablecondenser that will condense all the vapors dischargedfrom the pressure relief valve may be used in lieu of pipingthe vapors to the atmosphere. The pressure relief valve shallnot have a lifting lever. The vaporizer shall be designed inaccordance with the rules in this Code for a working pres-sure of at least 40 psi (280 kPa) above the operating pres-sure at which it will be used. Valve body drains are notmandatory.

PVG-12.2 Pressure relief valves shall be disconnectedfrom the vaporizer at least once yearly, when they shallbe inspected, repaired if necessary, tested, and thenreplaced on the vaporizer.

PVG-12.3 In order to minimize the loss by leakage ofmaterial through the pressure relief valve, a rupture diskmay be installed between the pressure relief valve andthe vaporizer, provided the requirements of PVG-12.3.1through PVG-12.3.4.3 are met.

PVG-12.3.1 The cross-sectional area of the connec-tion to a vaporizer shall be not less than the required reliefarea of the rupture disk.

PVG-12.3.2 Every rupture disk shall have a specifiedbursting pressure at a specified temperature, shall bemarked with a lot number, and shall be guaranteed by its



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2010 SECTION I

manufacturer to burst within 5% (plus or minus) of itsspecified bursting pressure.

PVG-12.3.3 The specified bursting pressure at thecoincident specified temperature shall be determined bybursting two or more specimens from a lot of the samematerial and of the same size as those to be used. The testsshall be made in a holder of the same form and pressurearea dimensions as that with which the disk is to be used.

PVG-12.3.4 A rupture disk may be installed betweena pressure relief valve and the vaporizer provided

PVG-12.3.4.1 The maximum pressure of therange for which the disk is designed to rupture does notexceed the opening pressure for which the pressure reliefvalve is set or the maximum allowable working pressureof the vessel.

PVG-12.3.4.2 The opening provided through therupture disk, after breakage, is sufficient to permit a flowequal to the capacity of the attached valve, and there is nochance of interference with the proper functioning of thevalve, but in no case shall this area be less than the inletarea of the valve.

PVG-12.3.4.3 The space between a rupture diskand the valve should be provided with a pressure gage,try cock, free vent, or a suitable telltale indicator. Thisarrangement permits the detection of disk rupture orleakage.1

PVG-12.4 Pressure relief valve discharge capacityshall be determined from the following equation:

W p CKAP � M / T

where

A p discharge area of pressure relief valveC p constant for vapor that is a function of the ratio

of Specific Heats k p cp /cv (see Fig. PVG-12)Note: Where k is not known, k p 1.001.

K p coefficient of discharge for the designM p molecular weightP p (set pressure � 1.03) + Atmosphere PressureT p absolute temperature at inlet, °F + 460 (°C +

273)W p flow of vapor

PVG-12.5 Pressure relief valves for organic fluidvaporizers shall be tested and certified under PG-69, andthey shall be stamped with the rated relieving capacity inpounds per hour at coincident temperature as determinedin PVG-12.4. The fluid identification shall be stamped onthe nameplate.

1 Users are warned that a rupture disk will not burst at its designedpressure if back pressure builds up in the space between the disk and thepressure relief valve, which will occur should leakage develop in therupture disk due to corrosion or other cause.

161

FIG. PVG-12 CONSTANT, C, FOR VAPOR RELATEDTO RATIO OF SPECIFIC HEATS (kpcp/cv)

400

390

380

370

360

350

340

330

320

1.0 1.2 1.4

k

1.6 1.8 2.0

Co

nst

ant,

C

Flow Formula Calculations

= K ( CAP M/T )

C = 520 k2

k + 1

k + 1k – 1( )

W

GENERAL NOTE: Flow formula calculations

W p K �CAP�M/T�(U.S. Customary Units)

C p 520� k � 2k + 1�k + 1

k - 1

(SI Units)

C p 39.48� k � 2k + 1�k + 1

k - 1

PVG-12.6 The required minimum pressure relief valverelieving capacity shall be determined from the followingequation:

W pC � H � 0.75

h

where

C p maximum total weight or volume of fuel burnedper hour, lb (kg) or ft3 (m3)

H p heat of combustion of fuel, Btu / lb (J/kg) orBtu /ft3 (J/m3) (see A-17)

h p latent heat of heat transfer fluid at relieving pres-sure, Btu /lb (J/kg)

W p weight of organic fluid vapor generated per hour

The sum of the pressure relief valve capacities marked onthe valves shall be equal to or greater than W.



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2010 SECTION I

PART PHRSGREQUIREMENTS FOR HEAT RECOVERY

STEAM GENERATORSPHRSG-1 GENERAL

The rules of this Part, PHRSG, shall be used in conjunc-tion with the general requirements of Part PG as well aswith the special requirements in the applicable parts of thisSection that apply to the method of fabrication used.

If a boiler meets the scope requirements of PHRSG-2,the rules of this Part shall supplement the rules for powerboilers and take precedence over them when there is aconflict.

PHRSG-2 SCOPE

The rules of this Part apply to a heat recovery steamgenerator, HRSG, which has as its principal source ofthermal energy a hot gas stream having high ramp ratesand temperatures such as the exhaust of a gas turbine.1

Such an HRSG may utilize supplemental firing and mayhave one or more superheaters, reheaters, evaporators,economizers, and/or feedwater heaters, which are housedin a common gas path enclosure. The sections cannot beindividually isolated from the gas stream.

PHRSG-3 REQUIREMENTS FORSUPERHEATER AND REHEATERCONDENSATE REMOVALCONNECTIONS

PHRSG-3.1 Each superheater and reheater shall beequipped with at least one condensate detection andremoval connection meeting all the following require-ments:

(a) The detection device shall utilize drain pots withdual element detection or single element detection withtime delay to close, or any other suitable detection andremoval method.

(b) Connections shall be capable of being opened underpressure so that condensate created during turbine purgecycles can be removed.

(c) Connections shall be sized and located such thatcondensate will be evaluated under all conditions.

1 The terms gas turbine and combustion turbine shall be consideredsynonymous and cover turbines burning liquid or gaseous fuels.

162

(d) Condensate removal piping required to be openedunder pressure shall meet the requirements of PHRSG-3.3and PHRSG-3.4.

Connections for the purpose of removing condensate arenot limited in size as defined by PG-59.3.5 and are permit-ted to serve also as the drain connection as required byPG-59.4.

PHRSG-3.2 Condensate removal piping as defined byPHRSG-3.1 from superheaters or reheaters of differentpressure levels that are required to be opened or operatedsimultaneously, and which discharge into a common col-lection device (e.g., manifold, blowdown tank, or flashtank), shall be designed so that when discharging, a highback pressure is not developed within the collection devicethat prevents flow or causes a reversal of flow. In addition,boiler components shall be designed such that condensatecannot flow from one superheater or reheater to anotheror from one part of a superheater or reheater to another.

PHRSG-3.3 Piping intended for removal of condensateor unvaporized water from steam spaces, such as superheat-ers or reheaters when the boiler is under pressure, shallextend through and include the second valve. The MAWPof the piping as required by PHRSG-3.1 and PHRSG-3.2shall be equal to the MAWP of the steam space that thecondensate removal piping is connected to plus the lesserof 25% of the MAWP or 225 psi (1.55 MPa).

PHRSG-3.4 All condensate removal piping shall havetwo quick-opening type valves and be routed to a blow-down tank, flash tank, manifold, or other connectiondevice. The collection device shall not be operated at ahigher pressure than the space being drained.

PHRSG-4 DESUPERHEATER DRAIN POTS

Where desuperheater spray water is injected into super-heater or reheater piping as a means to control steam tem-perature, the following shall be provided:

(a) Drain pots to detect and remove unvaporized spraywater shall be installed in the boiler proper or boiler exter-nal piping either upstream or downstream of the desuper-heater to ensure malfunctions of these devices will notallow water to enter hot boiler components. Drain pots



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2010 SECTION I

FIG. PHRSG-4 SOME ACCEPTABLE DESUPERHEATER SPRAYWATER PROTECTION DEVICE ARRANGEMENTS

Superheater or reheater

Reheater

Boiler setting



Boiler setting

Boiler setting

(a)

(c)(d)

(b)




Desuperheater

Drain pot assembly

ADMINISTRATIVE JURISDICTION AND TECHNICAL RESPONSIBILITIES

Boiler Proper—The ASME Boiler and Pressure Vessel Code (BPVC) has total administrative jurisdiction and technical responsibility (refer to Section I Preamble).

Boiler External Piping and Joint—The ASME BPVC has total administrative jurisdiction (mandatory certification by Code Symbol stamping, ASME Data Forms, and authorized inspection) of Boiler External Piping and Joint. The ASME Section Committee B31.1 has been assigned technical responsibility.

Non-Boiler External Piping and Joint—Not Section I jurisdiction (see applicable ASME B31 Code)

Boiler setting

163



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2010 SECTION I

TABLE PHRSG-4MINIMUM DRAIN POT SIZE

Attaching Pipe Size Minimum Drain Pot SizeNPS (DN) NPS (DN)

4 (100) 3 (75)6 (150) 4 (100)8 (200) 6 (150)

10 (250) 8 (200)12 (300) 10 (250)

14 (350) and larger 12 (300)

shall include automatic detection of water and automaticoperation of the drain pot valves as shown in Fig. PHRSG-4. Piping from the drain pot shall conform to the require-ments of PHRSG-3.

(b) Drain pot connection size shall be no smaller thanone NPS less than the pipe it is attached to, except it neednot be greater than NPS 12 (DN 300). See Table PHRSG-4.

164

(c) Drain pots, with single element level control withtime delay to close, are an acceptable method of detectingand removing unvaporized spray water.

(d) Piping layouts shall be sloped in all operating condi-tions so that unvaporized spray water from the desuper-heater cannot bypass the drain pot.

(e) All desuperheater drain piping shall be routed to ablowdown or flash tank, manifold, or other collectiondevice. The collection device shall not operate at a higherpressure than the space being drained.

PHRSG-5 CERTIFICATION

Manufacturer’s Data Reports shall be prepared in accor-dance with the requirements specified in Part PG. However,when the rules of Part PHRSG are used, each componentaffected shall be identified on the Manufacturer’s DataReport with the appropriate PHRSG paragraph referenced.



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2010 SECTION I

MANDATORY APPENDIX ISUBMITTAL OF TECHNICAL INQUIRIES TO THE

BOILER AND PRESSURE VESSEL COMMITTEE

I-1 INTRODUCTION

(a) This Appendix provides guidance to Code users forsubmitting technical inquiries to the Committee. SeeGuideline on the Approval of New Materials Under theASME Boiler and Pressure Vessel Code in Section II, PartsC and D for additional requirements for requests involvingadding new materials to the Code. Technical inquiriesinclude requests for revisions or additions to the Coderules, requests for Code Cases, and requests for Code inter-pretations, as described below.

(1) Code Revisions. Code revisions are considered toaccommodate technological developments, address admin-istrative requirements, incorporate Code Cases, or to clarifyCode intent.

(2) Code Cases. Code Cases represent alternatives oradditions to existing Code rules. Code Cases are writtenas a question and reply, and are usually intended to beincorporated into the Code at a later date. When used,Code Cases prescribe mandatory requirements in the samesense as the text of the Code. However, users are cautionedthat not all jurisdictions or owners automatically acceptCode Cases. The most common applications for CodeCases are to

(a) permit early implementation of an approvedCode revision based on an urgent need

(b) permit the use of a new material for Code con-struction

(c) gain experience with new materials or alterna-tive rules prior to incorporation directly into the Code

(3) Code Interpretations. Code Interpretations pro-vide clarification of the meaning of existing rules in theCode, and are also presented in question and reply format.Interpretations do not introduce new requirements. In caseswhere existing Code text does not fully convey the meaningthat was intended, and revision of the rules is required tosupport an interpretation, an Intent Interpretation will beissued and the Code will be revised.

(b) The Code rules, Code Cases, and Code Interpreta-tions established by the Committee are not to be consideredas approving, recommending, certifying, or endorsing anyproprietary or specific design, or as limiting in any way

165

the freedom of manufacturers, constructors, or owners tochoose any method of design or any form of constructionthat conforms to the Code rules.

(c) Inquiries that do not comply with the provisions ofthis Appendix or that do not provide sufficient informationfor the Committee’s full understanding may result in therequest being returned to the inquirer with no action.

I-2 INQUIRY FORMAT

Submittals to the Committee shall include(a) Purpose. Specify one of the following:

(1) revision of present Code rules(2) new or additional Code rules(3) Code Case(4) Code Interpretation

(b) Background. Provide the information needed for theCommittee’s understanding of the inquiry, being sure toinclude reference to the applicable Code Section, Division,Edition, Addenda, if applicable, paragraphs, figures, andtables. Preferably, provide a copy of the specific referencedportions of the Code.

(c) Presentations. The inquirer may desire or be askedto attend a meeting of the Committee to make a formalpresentation or to answer questions from the Committeemembers with regard to the inquiry. Attendance at a Com-mittee meeting shall be at the expense of the inquirer. Theinquirer’s attendance or lack of attendance at a meetingshall not be a basis for acceptance or rejection of the inquiryby the Committee.

I-3 CODE REVISIONS OR ADDITIONS

Requests for Code revisions or additions shall providethe following:

(a) Proposed Revisions or Additions. For revisions,identify the rules of the Code that require revision andsubmit a copy of the appropriate rules as they appear in theCode, marked up with the proposed revision. For additions,provide the recommended wording referenced to theexisting Code rules.

(10)



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(10)

2010 SECTION I

(b) Statement of Need. Provide a brief explanation ofthe need for the revision or addition.

(c) Background Information. Provide background infor-mation to support the revision or addition, including anydata or changes in technology that form the basis for therequest that will allow the Committee to adequately evalu-ate the proposed revision or addition. Sketches, tables,figures, and graphs should be submitted as appropriate.When applicable, identify any pertinent paragraph in theCode that would be affected by the revision or additionand identify paragraphs in the Code that reference theparagraphs that are to be revised or added.

I-4 CODE CASES

Requests for Code Cases shall provide a Statement ofNeed and Background Information similar to that definedin I-3(b) and I-3(c), respectively, for Code revisions oradditions. The urgency of the Code Case (e.g., projectunderway or imminent, new procedure, etc.) must bedefined and it must be confirmed that the request is inconnection with equipment that will be ASME stamped,with the exception of Section XI applications. The pro-posed Code Case should identify the Code Section andDivision, and be written as a Question and a Reply in thesame format as existing Code Cases. Requests for CodeCases should also indicate the applicable Code Editionsand Addenda, if applicable, to which the proposed CodeCase applies.

I-5 CODE INTERPRETATIONS

(a) Requests for Code Interpretations shall provide thefollowing:

(1) Inquiry. Provide a condensed and precise ques-tion, omitting superfluous background information and,when possible, composed in such a way that a “yes” or a“no” Reply, with brief provisos if needed, is acceptable.The question should be technically and editorially correct.

(2) Reply. Provide a proposed Reply that will clearlyand concisely answer the Inquiry question. Preferably, the

166

Reply should be “yes” or “no,” with brief provisos ifneeded.

(3) Background Information. Provide any back-ground information that will assist the Committee in under-standing the proposed Inquiry and Reply.

(b) Requests for Code Interpretations must be limitedto an interpretation of a particular requirement in the Codeor a Code Case. The Committee cannot consider consultingtype requests such as the following:

(1) a review of calculations, design drawings, weld-ing qualifications, or descriptions of equipment or parts todetermine compliance with Code requirements

(2) a request for assistance in performing any Code-prescribed functions relating to, but not limited to, materialselection, designs, calculations, fabrication, inspection,pressure testing, or installation

(3) a request seeking the rationale for Code require-ments

I-6 SUBMITTALS

Submittals to and responses from the Committee shallmeet the following:

(a) Submittal. Inquiries from Code users shall be inEnglish and preferably be submitted in typewritten form;however, legible handwritten inquiries will also be consid-ered. They shall include the name, address, telephone num-ber, fax number, and e-mail address, if available, of theinquirer and be mailed to the following address:

SecretaryASME Boiler and Pressure Vessel CommitteeThree Park AvenueNew York, NY 10016-5990

As an alternative, inquiries may be submitted via e-mailto: [email protected].

(b) Response. The Secretary of the ASME Boiler andPressure Vessel Committee or of the appropriate Subcom-mittee shall acknowledge receipt of each properly preparedinquiry and shall provide a written response to the inquirerupon completion of the requested action by the Code Com-mittee.



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2010 SECTION I

MANDATORY APPENDIX IISTANDARD UNITS FOR USE IN EQUATIONS

TABLE II-1STANDARD UNITS FOR USE IN EQUATIONS

Quantity U.S. Customary Units SI Units

Linear dimensions (e.g., length, height, thickness, radius, diameter) inches (in.) millimeters (mm)Area square inches (in.2) square millimeters (mm2)Volume cubic inches (in.3) cubic millimeters (mm3)Section modulus cubic inches (in.3) cubic millimeters (mm3)Moment of inertia of section inches4 (in.4) millimeters4 (mm4)Mass (weight) pounds mass (lbm) kilograms (kg)Force (load) pounds force (lbf) newtons (N)Bending moment inch-pounds (in.-lb) newton-millimeters (N·mm)Pressure, stress, stress intensity, and modulus of elasticity pounds per square inch (psi) megapascals (MPa)Energy (e.g., Charpy impact values) foot-pounds (ft-lb) joules (J)Temperature degrees Fahrenheit (°F) degrees Celsius (°C)Absolute temperature Rankine (R) kelvin (K)Fracture toughness ksi square root inches (ksi�in.) MPa square root meters (MPa�m)Angle degrees or radians degrees or radiansBoiler capacity Btu/hr watts (W)

167



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2010 SECTION I

MANDATORY APPENDIX IIICRITERIA FOR REAPPLICATION OF

AN ASME CODE SYMBOL STAMP

III-1 INTRODUCTION

After an item has been certified under ASME SectionI, if the ASME Code symbol stamping becomes indistinctor the nameplate is illegible or lost, but traceability to theoriginal certification can be established, the Code SymbolStamp may be reapplied to the item.

III-2 CONDITIONS

Reapplication of the ASME Code symbol shall only bepermitted under the following conditions:

(a) The Owner has requested the reapplication.(b) Where applicable, the jurisdiction has granted the

request for reapplication.(c) The reapplication shall be performed by the original

Manufacturer of the Code item. Where responsibility forthe original Code certification has been maintained, reap-plication by a successor organization to the original Manu-facturer is permitted.

(d) The reapplication shall be authorized and witnessedby an Inspector from an ASME-accredited Authorized

168

Inspection Agency, or by an authorized representative ofthe Qualified Inspection Organization or a Certified Indi-vidual, as applicable under the associated certificationprogram.

(e) Reapplication of the Code Symbol Stamp shall bedocumented on a Certificate of Conformance for Reappli-cation of the ASME Code Symbol Stamp as shown inForm III-1A. The completed Certificate of Conformancefor Reapplication of the ASME Code Symbol Stamp shallbe retained as required for the original Manufacturer’s DataReport.

III-3 RULES

Reapplication of the ASME Code symbol shall only beprovided to restore evidence of original compliance withASME Section I requirements. Reapplication of the ASMECode symbol shall not be applied for certification of thecurrent condition of the item or for certification to differentrequirements than originally constructed.



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2010 SECTION I

(10)

F1

F2

F3

F4 F5 F5 F5

F6F6F6F6

F7 F7 F7

F8

F9

F10

F12

F13

F14

F15

F16 F16

F17

F19

F17F17

F18

F20

F21 F21 F21

F13

F11 F11 F11

FORM III-1A CERTIFICATE OF CONFORMANCE FOR REAPPLICATION OF THE ASME CODE SYMBOL STAMP

In Accordance With Provisions of the ASME Boiler and Pressure Vessel Code

1. Manufactured by:

2. Manufactured for:

3. Location of Installation:

4. Item Description:

5. Item Identification:

6. Original Construction Code:

7. Traceability to Code Certification. (Attach a copy of the original Manufacturer’s Data Report.)

8. Remarks:

Authorization is requested to have the ASME Code symbol reapplied on the above described item in accordance with the

rules of the ASME Boiler and Pressure Vessel Code.

Owner

Signature Title Date

(Name and address)

(Name and address)

(Name and address)

(Name and address)

(Jurisdiction, if applicable)

(Name and address)

(Authorized Representative)



(Name of individual)

(inspector)

(Name and address)

(Name and address)

(Mfg. Data Report Form)(Boiler/pressure vessel, etc.) (Year built)

(Other)

(Code symbol applied)

(Jurisdiction no.)(National Board no.)(Manufacturer’s Serial no.)

(Name/Section/Division) (Edition/Addenda, if applicable) (Code Cases)

(07/10)

Authorization is granted to reapply the ASME Code Symbol Stamp on the above described item in accordance with the

rules of the ASME Boiler and Pressure Vessel Code.

Jurisdiction

Signature Date

I certify that to the best of my knowledge and belief, the statements in this Certificate of Conformance are correct and that the reapplication

of the ASME Code symbol is in accordance with provisions of the ASME Boiler and Pressure Vessel Code. Furthermore, it is understood

that reapplication of the ASME Code symbol is provided to restore evidence of original compliance with the construction code and is not to

be construed as endorsement of the identified item in its current condition.

Name of Original Manufacturer

Responsible Successor Organization

Signature Date

Code Symbol Stamp Certificate of Authorization No. Expiration Date

Inspected by Designated Oversight by � AIA � QIO � CI

Employer

Signature Date Commissions

169



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2010 SECTION I

(10)

F1

F2

F3

F4

F5

F6

F7

F8

F9

F10

F11

F12

F13

F14

F15

F16

F17

F18

F19

F21

F20

GUIDE FOR COMPLETING THE CERTIFICATE OF CONFORMANCE FOR

REAPPLICATION OF THE ASME CODE SYMBOL STAMP

Name and address of the original Manufacturer responsible for Code construction.

Name and address of the Purchaser and/or Owner.

Name and address of plant or facility where the item is installed.

Name of the item documented by this Certificate of Conformance.

Identify the Manufacturer’s data report form, Code symbol as originally applied to the item, and year built.

Provide identification of the item by applicable numbers as assigned by the Manufacturer.

Identify the Code name, section, division, edition, addenda (if applicable), and any code cases, as used for construction.

Describe the basis for establishing traceability of the identified item to the original Code certification. Attach a copy of the original Manufacturer’s data report. If reapplication is not performed under the same Certificate of Authorization number as the original construction, also describe the basis for establishing continuity to the original Manufacturer.

Provide any clarifications or additional information as may be appropriate.

Name and address of the Owner.

Signature, date, and title of Owner’s authorized representative requesting reapplication of the Code symbol stamping of the item.

Name of the jurisdiction granting authorization for reapplication of the Code symbol stamp. If not applicable, so indicate.

Signature and date of authorized representative from the jurisdiction granting authorization for reapplication of the Code symbol. If not applicable, so indicate.

Name and address of the original Manufacturer.

Name and address of responsible successor organization to the original Maunfacturer. If not applicable, so indicate.

Signature and date of authorized representative from the original Manufacturer or successor organization providing reapplication of the Code symbol.

Code symbol stamp, Certificate of Authorization number, and current expiration date under which the reapplication activity is performed.

Name of the individual providing verfication oversight of the reapplication activity.

Indicate the type of designated oversight in accordance with the associated certification program, i.e., ASME-accredited Authorization Inspection Agency, Qualified Inspection Organization, or Certified Individual.

Identify the employer’s name and address of the individual providing verfication oversight of the reapplication activity.

Signature, date, and, if applicable, jurisdictional commission of the individual providing verification oversight of the reapplication activity.

170



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2010 SECTION I

MANDATORY APPENDIX IVLOCAL THIN AREAS IN CYLINDRICAL SHELLS AND

IN SPHERICAL SEGMENTS OF HEADS

IV-1 SCOPE

The rules of this Mandatory Appendix permit the thick-ness of local thin areas (LTAs) to be less than the requiredthickness:

(a) in cylindrical shells under internal pressure requiredby PG-27

(b) in spherical segments of heads (such as hemispheri-cal heads and the spherical portion of torispherical andellipsoidal heads) under internal pressure on the concaveside required by PG-29.1 and PG-29.11

Local thin areas on the inside or outside of cylindricalshells or spherical segments of heads designed for internalpressure are acceptable, provided they meet the require-ments of this Mandatory Appendix.

IV-2 CYLINDRICAL SHELLS

The thickness of local thin areas on the inside or outsidesurface of a cylindrical shell designed for internal pressuremay be less than required by PG-27 provided the localthin areas satisfy the following rules:

(a) Nomenclature (see Fig. IV-2-1)

C p projected circumferential length of LTA, in.L p projected axial length of LTA, in.

LTA p local thin areatL p minimum thickness of LTA, in.� p see Fig. IV-2-1

See PG-27(b) for other nomenclature used in this Manda-tory Appendix.

(b) Single LTA(1) The single LTA shall satisfy the following equa-

tions:

t L

t≥ 0.9 (1)

L ≤ �(R · t) (2)

C ≤ 2�(R · t) (3)

t − t L ≤ 3⁄16 in. (4)

171

(2) No edge of an LTA shall be closer than2.5 �(R · t) from a structural discontinuity such as a heador stiffener.

(3) The minimum axial distance between the edge ofthe LTA and the edge of any nonreinforced opening shallbe equal to or greater than the inside diameter of the open-ing plus �(R · t).

(4) The minimum axial distance between the edge ofthe LTA and the reinforcement limit of a reinforced open-ing shall be equal to or greater than �(R · t).

(5) The blend between the LTA and the thicker sur-face shall be with a taper length not less than three timesthe LTA depth as shown in Fig. IV-2-1, illustration (b).The minimum bottom blend radius shall be equal to or

FIG. IV-2-1 SYMBOLS

LTA

L

C

(a)

Axial direction

Circumferential direction

Taper length (3) � (LTA depth)

LTA depth

L or C

(b)

Radius (2) � (LTA depth)

Chamfer or round the corner

(10)



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2010 SECTION I

FIG. IV-2-1 SYMBOLS (CONT’D)

Axial separation

Circumferential separation

LTA

LTA

(c)

L1

L2

greater than two times the LTA depth as shown in Fig. IV-2-1, illustration (b).

(6) The longitudinal stresses on the LTA frommechanical loads other than internal pressure shall notexceed 0.3S.

(7) These requirements shall only be applied at thetemperatures where the allowable stresses listed in allow-able stress tables in Section II, Part D are not controlledby time-dependent properties.

(c) Multiple LTAs. A pair of local thin areas with fin-ished axial length L1 and L2 are acceptable if the individualLTA satisfies the requirements of (b) above, either condi-tion in (c)(1) or (c)(2) below is met, and the requirementsin (c)(3) through (c)(6) below are met.

(1) When � ≤ 45 deg, the minimum axial separation[see Fig. IV-2-1, illustration (c)] shall be the greater of

(1.0 + 1.5cos�)(L1 + L2)2

or 2t

(2) When � > 45 deg, both of the following shallbe met:

(a) The minimum axial separation shall be equalto or greater than

2.91cos�(L1 + L2)2

(b) The minimum circumferential separation shallbe equal to or greater than 2t.

(3) Multiple pairs of LTA are acceptable providedall pairs meet the rules of a single pair specified in subpara.(c)(2)(b) above.

(4) Multiple local thin areas may be combined as asingle LTA. The resultant single LTA is acceptable if itsatisfies the rules of (c)(2)(a) above.

(d) Recording Location of LTAs. The required minimumthickness t and the dimensions tL, L, and C of the LTA

172

shall be noted on the Manufacturer’s Data Report. Thelocation of the LTA shall be specified in sufficient detailon the Manufacturer’s Data Report to identify it clearly tothe end user and the in-service inspector.

(e) Code Requirements. All other applicable Coderequirements shall be met.

(f) Manufacturer’s Data Report. The use of this Manda-tory Appendix shall be shown on the Manufacturer’s DataReport.

IV-3 SPHERICAL SEGMENTS OF HEADS

The thickness of local thin areas on the inside or outsidesurface of spherical segments of heads (such as hemispheri-cal heads and the spherical portion of torispherical andellipsoidal heads) under pressure on the concave side, maybe less than required by PG-29.1 and PG-29.11 providedthe local thin areas satisfy the following conditions:

(a) Nomenclature (See Figs. IV-3-1 through IV-3-5)

DL p maximum dimension of LTA, in.LTA p local thin area

R p inside radius for spherical segment, in.t p required head thickness per PG-29, in.

tL p minimum thickness of LTA, in.

(b) Single LTA(1) The single LTA shall satisfy the following equa-

tions:

t L

t≥ 0.9 (1)

DL ≤ �(R · t) (2)

t − t L ≤ 3⁄16 in. (3)

(2) The minimum distance between the edge of theLTA and the edge of any unreinforced opening shall beequal to or greater than the inside diameter of the openingplus �(R · t).

(3) The minimum distance between the edge of theLTA and the reinforcement limit of a reinforced openingshall be equal to or greater than �(R · t).

(4) No edges of an LTA shall be closer than 2.5�(R · t) from a structural discontinuity.

(5) A constant thickness junction between head andcylindrical shell is not considered a discontinuity forLTA rules.

(6) The blend between the LTA and the thicker sur-face shall be with a taper length not less than three timesthe LTA depth. The minimum bottom blend radius shallbe equal to or greater than two times the LTA depth. Theblend requirements are shown in Fig. IV-3-1.

(7) The LTA for a torispherical head must lie entirelywithin the spherical portion of the head. See Fig. IV-3-2.



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2010 SECTION I

FIG. IV-3-1 BLEND REQUIREMENTS

Radius 2 �(LTA depth)

Taper length 3 � (LTA depth)

LTA depth

DL

Chamfer or roundthe corner

FIG. IV-3-2

Spherical portion LTA limit

Knuckle

FIG. IV-3-3

0.8D LTA limit

D

h

(8) The LTA for an ellipsoidal head must lie entirelywithin a circle, the center of which coincides with the axisof the vessel and the diameter of which is equal to 80%of the shell inside diameter. See Fig. IV-3-3.

(9) The LTA for a hemispherical head is acceptablewithin any portion of the head except as limited by (b)(4)above. See Fig. IV-3-4.

(10) The provisions of these rules do not apply to theknuckle portion of a torispherical or to the region outsidethe region of an ellipsoidal head or to flat heads.

(11) These rules shall only be applied at temperatureswhere the allowable stresses listed in the allowable stresstables in Section II, Part D are not controlled by time-dependent properties.

173

FIG. IV-3-4

LTA limit

D

Sh

ell

Hea

d

FIG. IV-3-5

LTA limit [See IV-3(b)(3)]

D

Sh

ell

Hea

d

2.5 Rt

(c) Multiple LTAs(1) Multiple LTAs may be combined and evaluated

as a single LTA. The encompassed areas of the combinedLTAs shall be within the DL dimension.

(2) Each LTA in the encompassed area shall meetthe rules of (b)(1) above.

(3) Multiple LTAs may be treated as single LTAsprovided their edges are no closer than 2.5 �(R · t).

(d) Recording Locations of LTAs. The location anddimensions tL and DL of the LTA shall be noted on theManufacturer’s Data Report.

(e) Code Requirements. All other applicable coderequirements shall be met.

(f) Manufacturer’s Data Report. The use of this Manda-tory Appendix shall be shown on the Manufacturer’s DataReport.



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2010 SECTION I

NONMANDATORY APPENDIX AEXPLANATION OF THE CODE CONTAINING MATTER

NOT MANDATORY UNLESS SPECIFICALLYREFERRED TO IN THE RULES OF THE CODE

BRACED AND STAYED SURFACES(See Fig. A-8)

A-8

The allowable loads based on the net cross-sectionalareas of staybolts with V-threads are computed from thefollowing equations. The use of Whitworth threads withother pitches is permissible.

The equation for the diameter of a staybolt at the bottomof a V-thread is

D − (P � 1.732) p d

where

D p diameter of staybolt over the threadsd p diameter of staybolt at bottom of threadsP p pitch of threads

p 1/number of threads /in. (25 mm)1.732 p a constant

When ASME Standard threads are used, the equationbecomes

D − (P � 1.732 � 0.75) p d

METHOD OF CHECKING PRESSURERELIEF VALVE CAPACITY BY

MEASURING MAXIMUM AMOUNT OFFUEL THAT CAN BE BURNED

A-12

The maximum quantity of fuel C that can be burned perhour at the time of maximum forcing is determined by atest. The maximum number of heat units per hour, or CH,is then determined, using the values of H given in A-17.The weight of steam generated per hour is found by thefollowing equation:


W pC � H � 0.75

1,100

174

(SI Units)

W pC � H � 0.75

2 558

where

C p total weight or volume of fuel burned/hr at timeof maximum forcing, lb/hr (kg/hr) or ft3/hr (m3/hr)

H p heat of combustion of fuel, Btu / lb (kJ/kg) orBtu /ft3 (kJ/m3) (see A-17)

W p weight of steam generated /hr, lb (kg/hr)

The sum of the pressure relief valve capacities markedon the valves shall be equal to or greater than W.

A-13 EXAMPLE 1

A boiler at the time of maximum forcing uses 2,150 lb/hrof Illinois coal with a heating value of 12,100 Btu/lb. Boilerpressure is 225 psi gage.

C � H p 2,150 � 12,100 p 26,015,000

W pC � H � 0.75

1,100p 17,740

A-14 EXAMPLE 2

Wood shavings of heat of combustion of 6,400 Btu/ lbare burned under a boiler at the maximum rate of2,000 lb/hr. Boiler pressure is 100 psi gage.

C � H p 2,000 � 6,400 p 12,800,000

W pC � H � 0.75

1,100p 8,730



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2010 SECTION I

FIG. A-8 DETAIL SKETCHES SHOWING APPLICATION OF PG-48 AND PFT-27 TO THE STAYING OF BOILERS

Fillet weld (see PFT-11.3)

r

p

p

p

Min. (see PW-13)

t

(a-1) (a-2)

(b-1) (b-2)

Max. r = 8t

Min. t = 3t

t = nominal thickness of tubesheet

C = 2.1 or 2.2C = 2.1 or 2.2Max. r = 8t

Min. r = 3t

P = 3.2 ×t sp

2

2

P = 3.2 ×t sp

2

2

P = C ×t sp

2

2 P = C ×t sp

2

2

Fillet weld (see PFT-11.3)

Screwed staybolt with end riveted over (see PG-47)

Door ringDoor ring

Welded staybolt heads (see PW-19)

Full penetration weld (see PW-11.4)

Full penetration weld (see PFT-11.4)

Full penetration weld (see PFT-11.4)

r

r

tt t

Min. (see PW-13)

Combustion chamber head

Boiler head

Full penetration weld (see PW-19)Full penetration

weld (see PW-11.4)Full penetration weld (see PW-19)

Where “p” is same as given in P-46


p

t

r

t t

r

pTwo fillet welds (see PFT-11.3)Boiler shell

(c)

Max. r = 8tMin. r = 3t

C = 2.1 or 2.2

P = C ×t sp

2

2

(g) (h)


Full penetration weld (see PW-19)

Full penetration weld (see PW-11.4)

ß

ß = Angularity of tangent lines in degrees

p

t

t

t

p

p

P = 2.2 ×t sp

2

2

290ß

×

p/2 + 2 in. (50 mm)

p/2 + 2 in. (50 mm)

P/2 + 2 in.

t

175



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2010 SECTION I

FIG. A-8 DETAIL SKETCHES SHOWING APPLICATION OF PG-48 AND PFT-27 TO THE STAYING OF BOILERS(CONT’D)

1/2 in. (13 mm) min.

11/2 p max.

(i)

(k)

(o) (p)

(l) Door Opening

Full penetration weld may be applied from either or both sides

Full penetration weld may be applied from either or both sides of tubesheet

Grind flush

(1) Weld in shear PW-19.1(2) Maximum pitch 15 times stay diameter PFT-27.2(3) Max. r = 8 t Min. r = 3 t t = Nominal thickness of tubesheet

Area

p

r

t t

Area

2(1) Weld in shear PW-19.1(2) Maximum pitch 15 times stay diameter PFT-27.3

p

(j)

(1) Weld in shear PW-19.1(2) Maximum pitch 15 times stay diameter PFT-27.2(3) Max. r = 8 t Min. r = 3 t t = Nominal thickness of tubesheet

Area

p

r

+ 2 in. (50 mm)

2p

+ 2 in.(50 mm) max.

p max.

(n) Door Opening

or Mud Ring

2p

+ 2 in.(50 mm)

p max.

p max.

(m) Door Opening

or Mud Ring

2p

+ 2 in.(50 mm) max.

p max.

Tube

Wrapper or crown sheet

p

176



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2010 SECTION I

FIG. A-8 DETAIL SKETCHES SHOWING APPLICATION OF PG-48 AND PFT-27 TO THE STAYING OF BOILERS(CONT’D)

2

(1) Provide stay cross-sectional area required by PG-49 based upon allowable stresses from Table 1A of Section II, Part D.

(2) Provide the number of stays required to not exceed the maximum calculated pitch.

(3) Diagonal stay stresses must not exceed limits computed from PFT-32.

p

2p

2p

2p

2p

+ 2 in. (50 mm) (PFT-27.3)

2p

+ 2 in. (50 mm) (PFT-27.3)

2p

max.

p

p

p p

p

p

p

PFT27.9.2 PFT-27.9.1

11/16 in.(17 mm)Minimumbearingsurface

(PG-44.3)

PFT-27.1

(PFT-27.1)p max.

(q)

Maximum pitch ”p“ may be measured horizontally and vertically only

Maximum pitch ”p“ may measured circumferentially and radially only

2

(1) Provide stay cross-sectional area required by PG-49 based upon allowable stresses from Table 1A of Section II, Part D.

(2) Provide the number of stays required to not exceed the maximum calculated pitch.

(3) Diagonal stay stresses must not exceed limits computed from PFT-32.

p

2p

2p

2p

PFT-27.2

PFT-27.22p

rmax.

2p

max.

p

p

p

p

p

p

p

p

p

PFT27.9.2

PFT-27.9.1

11/16 in.(17 mm)

Minimumbearing

surface (PG-44.3)11/16 in.

(17 mm) Minimum

bearing surface

PFT-27.1

(PFT-27.1)p max.

(r)

Maximum pitch ”p“ may be measured horizontally and vertically only

Maximum pitch ”p“ may be measured circumferentially and radially only

r

177



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2010 SECTION I

A-15 EXAMPLE 3

An oil-fired boiler at maximum forcing uses 1,000 lb /hrof crude oil (Texas). Boiler pressure is 275 psi gage.

C � H p 1,000 � 18,500 p 18,500,000

W pC � H � 0.75

1,100p 12,620

A-16 EXAMPLE 4

A boiler fired with natural gas consumes 3,000 ft3 /hr.The working pressure is 150 psi gage.

C � H p 3,000 � 960 p 2,880,000

W pC � H � 0.75

1,100p 1,960

A-17

For the purpose of checking the pressure relief valvecapacity as described in A-12, the following values of heatsof combustion of various fuels may be used:

Fuel Type H, Btu /lb (kJ/kg)

Semibituminous coal 14,500 (34 000)Anthracite 13,700 (32 000)Screenings 12,500 (29 000)Coke 13,500 (31 000)Wood, hard or soft, kiln dried 7,700 (18 000)Wood, hard or soft, air dried 6,200 (14 000)Wood shavings 6,400 (14 400)Peat, air dried, 25% moisture 7,500 (17 000)Lignite 10,000 (23 300)Kerosene 20,000 (46 500)Petroleum, crude oil, Pennsylvania 20,700 (48 000)Petroleum, crude oil, Texas 18,500 (43 000)

Fuel Type H, Btu /ft3 (kJ/m3)

Natural gas 960 (35 700)Blast-furnace gas 100 (3 700)Producer gas 150 (5 600)Water gas, uncarbureted 290 (11 000)

AUTOMATIC WATER GAGES

A-18

Automatic shutoff valves intended to restrict the flowfrom a damaged water gage without human interventionshall conform to the requirements of A-18.1 through A-18.6.

A-18.1 Check valves in upper and lower fittings shallbe of solid noncorrosive metal ball type to avoid need forguides.

178

A-18.2 Ball check valves in upper and lower fittingsmust open by gravity and the lower ball check valve mustrise vertically to its seat.

A-18.3 The check balls must be not smaller than 1⁄2 in.(13 mm) in diameter, and the diameter of the circle ofcontact with the seat must be not greater than two-thirdsof the diameter of the check ball. The space around eachball must be not less than 1⁄8 in. (3.0 mm), and the travelmovement from the normal resting place to the seat mustbe not less than 1⁄4 in. (6 mm).

A-18.4 The ball seat in the upper fitting must be a flatseat with either a square or hexagonal opening, or otherwisearranged so that the steam passage can never be completelyclosed by this valve.

A-18.5 The shutoff valve in the upper fitting must havea projection that holds the ball at least 1⁄4 in. (6 mm) awayfrom its seat when the shutoff valve is closed.

A-18.6 The balls must be accessible for inspection.Means must be provided for removal and inspection of thelower ball check valve while the boiler is under steampressure.

These restrictions do not apply to closing the valves byexternal methods.

FUSIBLE PLUGS(See Fig. A-19)

A-19A-19.1 Fire-actuated fusible plugs, if used, except as

provided in A-20.9, shall be filled with tin of the followingcomposition, having a melting point between 445°F and450°F (229°C and 232°C):Pure tin, min . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 99.3%Copper, max. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 00.5%Lead, max . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 00.1%

Total impurities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 00.7%

A-19.2 The fusible metal shall extend from the waterend of the plug to the point of least diameter of the holeand shall be carefully alloyed to the casing. A test shallbe made to determine that the fusible metal is not loosein the plug.

A-19.3 Fusible plugs shall be replaced at least onceeach year. Casings that have been used shall not be refilled.

A-19.4 Fusible plugs filled with tin as specified inA-19.1 shall not be used for pressures and temperaturesthat will cause the plug to fail while it is submerged in theboiler water.

The fusible metal may be partly replaced by a bronzeplug loosely fitted to the hole and of such size that it willpass freely through the hole on the fire side, from which



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2010 SECTION I

FIG. A-19 TYPICAL FORMS OF FUSIBLE PLUGS

1/2 in. (13 mm)

3/4 in. (19 mm)

1/2 in. (13 mm)

1/2 in. (13 mm)

3/8 in. (10 mm)

1 in. (25 mm)

1/2 in. (13 mm)

3/4 in. (19 mm)1 in. (25 mm)

1/2 in. (13 mm)

Plug type

1/2 in. (13 mm)

Plug type

Installation

Installation

Installation

3/8 in. (10 mm)

1/2 in. (13 mm)

1 in. (10 mm)

1/2 in. (13 mm)

Plug type

3/8 in. (10 mm)

(a) Water side plugs

(b) Fire side plugs

GENERAL NOTE: All dimensions minimum unless otherwise specified

3/4 in. (19 mm)

1 in.(25 mm) max.

side it must be inserted into the casing. Such plug shall beproperly alloyed to the casing with the same fusible metalas required by A-19.1.

A-20A-20.1 Water side plugs are fusible plugs that are

inserted from the water side of the plate, flue, or tube towhich they are attached. Fire side plugs are fusible plugsinserted from the fire side of the plate, flue, or tube towhich they are attached.

A-20.2 The casing of the fusible plugs shall be madeof a composition conforming to SB-61 or from phosphor-bronze rods conforming to ASTM B 139.

A-20.3 Typical designs of fusible plugs are given inFig. A-19.

179

A-20.4 The bore of the casing shall be tapered continu-ously from the water end of the casing for a distance ofat least 1 in. to a diameter of not less than 3⁄8 in. (10 mm)at a point not less than 1⁄2 in. (13 mm) from the fire end.The diameter of the bore at either end shall be not lessthan 1⁄2 in. (13 mm). The hole on the fire end shall be aslarge as possible and may be of any shape provided thecross-sectional area at all points is greater than the area ofthe least cross section of the fusible metal.

A-20.5 A fusible plug shall be of such length that wheninstalled it shall project at least 3⁄4 in. (19 mm) on the waterside of the plate, tube, or flue. It shall extend through theplate, tube, or flue on the fire side as little as possible butnot more than 1 in. (25 mm).

A-20.6 A fire side plug may be designed so as to beinserted by means of a plug type wrench, so as to reducethe projection on the fire side.



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2010 SECTION I

A-20.7 If a fire-actuated fusible plug is inserted in atube, the tube wall at the plug shall not be less than 0.22 in.(5.6 mm) thick, or sufficient to give four full threads.

A-20.8 Fusible plugs that comply with the requirementsof A-19 and A-20 must be stamped on the casing with thename of the manufacturer, and on the water end of thefusible metal “ASME Std.”

A-20.9 Fusible metal, other than tin as specified inA-19.1, for use under temperatures exceeding 450°F(229°C), may be used and the casing may be made of othermaterial and shape than specified in A-20.2 through A-20.4if the metal and the casing are approved by the administra-tive authority. Such plugs shall not be marked as“ASME Std.”

A-21

Fire-actuated fusible plugs, if used, shall be located atthe lowest permissible water level as determined by theboiler Manufacturer; steam-actuated plugs, if used, shallbe so located that they will operate when the water levelis at the point where a fire-actuated fusible plug would belocated.

PROOF TESTS TO ESTABLISHMAXIMUM ALLOWABLE WORKING

PRESSURE

A-22A-22.1 Scope. The maximum allowable working pres-

sure for pressure parts of boilers for which the strengthcannot be computed with a satisfactory assurance of accu-racy shall be established in accordance with the require-ments of this paragraph, using one of the test proceduresapplicable to the type of loading and to the material usedin its construction.

The tests in these paragraphs may be used only for thepurpose of establishing the maximum allowable workingpressure of those elements or component parts for whichthe thickness cannot be determined by means of the designrules given in this Code. The maximum allowable workingpressure of all other elements or component parts shall notbe greater than that determined by means of the applicabledesign rules.

A-22.2 TestsA-22.2.1 Types. Provision is made for two types

of tests for determining the internal maximum allowableworking pressure

A-22.2.1.1 Tests based on yielding of the part tobe tested. These tests are limited to materials with a ratio

180

of minimum specified yield to minimum specified ultimatestrength of 0.625 or less.

A-22.2.1.2 Tests based on bursting of the part.

A-22.2.2 Retests. A retest shall be allowed on aduplicate pressure part if errors or irregularities are obviousin the test results.

A-22.2.3 Precautions. Safety of testing personnelshould be given serious consideration when conductingproof tests, and particular care should be taken duringbursting tests in A-22.6.3.

A-22.3 PressureA-22.3.1 Previously Applied. The pressure parts for

which the maximum allowable working pressure is to beestablished shall not previously have been subjected to apressure greater than 11⁄2 times the desired or anticipatedmaximum allowable working pressure, adjusted for designtemperature as provided in A-22.8.

A-22.3.2 Application. In the procedures given inA-22.6.1 for the Strain Measurement Test, and A-22.6.2for the Displacement Measurement Test, the hydrostaticpressure in the pressure part shall be increased graduallyuntil approximately one-half the anticipated maximumallowable working pressure is reached. Thereafter, the testpressure shall be increased in steps of approximately one-tenth or less of the anticipated maximum allowable work-ing pressure until the pressure required by the test proce-dure is reached. The pressure shall be held stationary atthe end of each increment for a sufficient time to allowthe observations required by the test procedure to be made,and shall be released to zero to permit determination ofany permanent strain or displacement after any pressureincrement that indicates an increase in strain or displace-ment over the previous equal pressure increment.

A-22.4 Critical Areas. As a check that the measure-ments are being taken on the most critical areas, the Inspec-tor may require a brittle coating to be applied on all areasof probable high stress concentrations in the test proceduresgiven in A-22.6.1 and A-22.6.2. The surfaces shall besuitably clean before the coating is applied in order toobtain satisfactory adhesion. The technique shall be suitedto the coating material.

NOTE: Strains should be measured as they apply to membrane stressesand to bending stresses within the following range. It is recognized thathigh localized and secondary bending stresses may exist in pressureparts designed and fabricated in accordance with these rules. Insofar aspractical, design rules for details have been written to hold such stressesat a safe level consistent with experience.

A-22.5 Yield Strength and Tensile Strength. Forproof tests based on yielding, A-22.6.1 or A-22.6.2, theyield strength (or yield point for those materials whichexhibit that type of yield behavior indicated by a “sharp-kneed” portion of the stress–strain diagram) of the material



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2010 SECTION I

in the part tested, shall be determined in accordance withthe method prescribed in the applicable material specifica-tion and as described in ASTM E 8, Tension Testing ofMetallic Materials. For proof tests based on bursting,A-22.6.3, the tensile strength instead of the yield strength ofthe material in the part tested shall be similarly determined.

Yield or tensile strength so determined shall be the aver-age from three or four specimens cut from the part testedafter the test is completed. The specimens shall be cut froma location where the stress during the test has not exceededthe yield strength. The specimens shall not be oxygen cutbecause this might affect the strength of the material.

When excess stock from the same piece of wroughtmaterial is available and has been given the same postweldheat treatment as the pressure part, the test specimens maybe cut from this excess stock. The specimens shall not beremoved by flame cutting or any other method involvingsufficient heat to affect the properties of the specimen.

If yield or tensile strength are not determined by testspecimens from the pressure part tested, alternative meth-ods are given in A-22.6.1, A-22.6.2, and A-22.6.3 for evalu-ation of proof test results to establish the maximumallowable working pressure.

A-22.6 ProcedureA-22.6.1 Strain Measurement Test

A-22.6.1.1 Subject to limitations of A-22.2.1.1,this procedure may be used for pressure parts under internalpressure, constructed of any material permitted to be usedunder the rules of Section I. Strains shall be measured inthe direction of the maximum stress at the most highlystressed parts (see A-22.4) by means of strain gages ofany type capable of indicating strains to 0.00005 in./in.Pressure shall be applied as provided in A-22.3.2.

A-22.6.1.2 After each increment of pressure hasbeen applied, readings of the strain gages and the hydro-static pressure shall be taken and recorded. The pressureshall be released and any permanent strain at each gageshall be determined after any pressure increment that indi-cates an increase in strain for this increment over the previ-ous equal pressure increment. Only one application of eachincrement of pressure is required.

A-22.6.1.3 Two curves of strain against test pres-sure shall be plotted for each gage line as the test prog-resses, one showing the strain under pressure and oneshowing the permanent strain when the pressure isremoved. The test may be discontinued when the test pres-sure reaches the value H, which will, by the formula, justifythe desired working pressure but shall not exceed the pres-sure at which the plotted points for the most highly strainedgage line reaches the value given below for the materialused.

A-22.6.1.3.1 0.2% permanent strain for carbon,low-alloy and high-alloy steels.

181

A-22.6.1.3.2 0.5% strain under pressure forcopper-base alloys.

A-22.6.1.3.3 0.2% permanent strain for nickelalloys.

A-22.6.1.4 The maximum allowable workingpressure P in pounds per square inch at test temperaturefor parts tested under this paragraph shall be computed byone of the following equations.

A-22.6.1.4.1 If the average yield strength isdetermined by A-22.5

P p 0.5HYs

Ya

A-22.6.1.4.2 If the actual average yield strengthis not determined by test specimens

P p 0.4H

where

H p hydrostatic test pressure, at which the test wasstopped in accordance with A-22.6.1.3

Ya p yield strength — actual average from test spec-imens

Ys p yield strength — specified minimum

The maximum allowable working pressure at other tem-peratures shall be determined as provided in A-22.8.

A-22.6.2 Displacement Measurement TestA-22.6.2.1 Subject to the limitations of A-22.2.1.1

this procedure may be used only for pressure parts underinternal pressure, constructed of materials having a defi-nitely determinable yield point. Displacement shall be mea-sured at the most highly stressed parts (see A-22.4) bymeans of measuring devices of any type capable of measur-ing to 0.001 in. (0.02 mm). This displacement may bemeasured between two diametrically opposed referencepoints in a symmetrical structure, or between a referencepoint and a fixed base point. Pressure shall be applied asprovided in A-22.3.2.

A-22.6.2.2 After each increment of pressure hasbeen applied, readings of the displacement and the hydro-static pressure shall be taken and recorded. The pressureshall be released and any permanent displacement shall bedetermined after any pressure increment that indicates anincrease in measured displacement for this increment overthe previous equal pressure increment. Only one applica-tion of each increment is required. Care must be taken toassure that the readings represent only displacements ofthe parts on which measurements are being made and donot include any slip of the measuring devices or any move-ment of the fixed base points or of the pressure part as awhole.

A-22.6.2.3 Two curves of displacement againsttest pressure shall be plotted for each reference point as



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2010 SECTION I

the test progresses, one showing the displacement underpressure, and one showing the permanent displacementwhen the pressure is removed. The application of pressureshall be stopped when it is evident that the curve throughthe points representing displacement under pressure hasdeviated from a straight line.

A-22.6.2.4 The pressure coincident with the pro-portional limit of the material shall be determined by notingthe pressure at which the curve representing displacementunder pressure deviates from a straight line. The pressureat the proportional limit may be checked from the curveof permanent displacement by locating the point where thepermanent displacement begins to increase regularly withfurther increases in pressure. Permanent deformation at thebeginning of the curve that results from the equalizationof stresses and irregularities in the material may be disre-garded.

The maximum allowable working pressure P in poundsper square inch at test temperature for parts tested underthis paragraph shall be computed by one of the followingequations.

A-22.6.2.4.1 If the average yield strength isdetermined by A-22.5

P p 0.5HYs

Ya

A-22.6.2.4.2 In order to eliminate the necessityof cutting tensile specimens and determining the actualyield strength of the material under test, one of the follow-ing equations may be used to determine the maximumallowable working pressure.

A-22.6.2.4.2.1 For carbon steel, meeting anacceptable Code specification, with a specified minimumtensile strength of not over 70,000 psi (480 MPa)


P p 0.5H � SS + 5,000�

(SI Units)

P p 0.5H � SS + 34.5�

A-22.6.2.4.2.2 For any material listed inTables 1A and 1B of Section II, Part D, as acceptable forSection I construction

P p 0.4H

where

H p hydrostatic test pressure coincident with the pro-portional limit of the weakest element of the com-ponent part tested

S p specified minimum tensile strength

182

Ya p yield strength — actual average from test spec-imens

Ys p yield strength — specified minimum

When the equation in A-22.6.2.4.2.1 or A-22.6.2.4.2.2is used, the material in the pressure part shall have had noappreciable cold working or other treatment that wouldtend to raise the yield strength above the normal.

The maximum allowable working pressure at other tem-peratures shall be determined as provided in A-22.8.

A-22.6.3 Bursting TestsA-22.6.3.1 This procedure may be used for pres-

sure parts under internal pressure when constructed of anymaterial permitted to be used under the rules of Section I.The maximum allowable working pressure of any compo-nent part proof tested by this method shall be establishedby a hydrostatic test to failure by rupture of a full-sizesample of such pressure part. The hydrostatic pressure atwhich rupture occurs must be determined. Alternatively,the test may be stopped at any pressure before rupture thatwill satisfy the requirements for the desired maximumallowable working pressure. The item so tested shall notbe used for Code construction.

A-22.6.3.2 The maximum allowable workingpressure P in pounds per square inch at test temperaturefor parts tested under this paragraph shall be computed byone of the following equations.

A-22.6.3.2.1 Parts constructed of materialsother than cast materials

P pB4

�S

(Sa or Sm)

A-22.6.3.2.2 Parts constructed of cast iron

P pB

6.67�

SSb

A-22.6.3.2.3 Parts constructed of nodular iron

P pBf5

�S

Sb

A-22.6.3.2.4 For parts constructed of cast mate-rials, except cast iron and nodular iron

P pBf4

�S

(Sa or Sm)

where

B p bursting test pressuref p casting quality factor as defined in PG-25S p specified minimum tensile strength

Sa p average actual tensile strength of test specimensSb p minimum tensile strength of test barSm p maximum tensile strength of range of specifi-

cation



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2010 SECTION I

For all materials except cast iron and nodular iron, themaximum allowable working pressure at other tempera-tures shall be determined as provided in A-22.8.

A-22.7 Parts Subject to Collapse

A-22.7.1 Parts of the boiler normally subject to col-lapse for which specified rules are not provided in thisSection shall withstand without excessive deformation ahydrostatic test of not less than three times the desiredmaximum allowable working pressure.

A-22.7.2 The maximum allowable working pressureat other than test temperatures shall be determined as pro-vided in A-22.8.

A-22.8 Higher Temperatures. The maximum allow-able working pressure for pressure parts that are designedfor temperatures at which the allowable stress value of thematerial is less than that at the test temperature shall bedetermined by the following equation:

Po p PtSo

St

where

Po p maximum allowable working pressure at designtemperature

Pt p maximum allowable working pressure at test tem-perature

So p maximum allowable stress value at the designtemperature, as given in Table 1A or 1B of SectionII, Part D

St p maximum allowable stress value at test tempera-ture as given in Table 1A or 1B of Section II,Part D

A-22.9 Duplicate Parts. When the maximum allowableworking pressure of a pressure part has been establishedby a proof test, duplicate parts of the same materials, designand construction need not be proof tested but shall be giventhe standard hydrostatic test at 11⁄2 times the maximumallowable working pressure. The dimensions and minimumthickness of the structure to be tested should not varymaterially from those actually used. A geometrically simi-lar part may be qualified by a series of tests covering thecomplete size range of the pressure part.

A-22.10 Inspection. Tests to establish the maximumallowable working pressure for pressure parts shall be wit-nessed and approved by an Authorized Inspector.

A-22.11 Test Gages

A-22.11.1 An indicating gage shall be connecteddirectly to the pressure parts. If the indicating gage isnot readily visible to the operator controlling the pressureapplied, an additional indicating gage shall be providedwhere it will be visible to the operator throughout the

183

duration of the test. For large pressure parts, it is recom-mended that a recording gage be used in addition to indicat-ing gages.

A-22.11.2 Pressure gages used in testing shall com-ply with PG-99.4.

A-22.11.3 All gages used in proof testing shall becalibrated against a standard deadweight tester or a cali-brated master gage before the proof test is begun. Gagesshall be recalibrated at any time that there is reason tobelieve they are in error.

A-24 TABLE PG-23.1

See Table 1A of Section II, Part D.

A-25 TABLE PG-23.2

See Table 1B of Section II, Part D.

A-26 TABLE PG-23.3

See Table 1B of Section II, Part D.

A-27 TABLE PG-23.4

See Table Y-1 of Section II, Part D.

A-28 FIGURES G AND CS-1 THROUGHCS-6

See Subpart 3, External Pressure Charts in Section II,Part D.

SUGGESTED RULES COVERINGEXISTING INSTALLATIONS

A-30

For existing riveted construction, use suggested rules inthe 1971 Edition of Section I.

PRESSURE RELIEF VALVES FORPOWER BOILERS

A-44

The minimum pressure relief valve relieving capacityfor other than electric boilers, waste heat boilers, organicfluid vaporizers, and forced-flow steam generators with nofixed steam and waterline, when provided in accordancewith PG-67.4.3, may be estimated on the basis of thepounds of steam generated per hour per square foot (kilo-



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2010 SECTION I

TABLE A-44GUIDE FOR ESTIMATING STEAMING

CAPACITY BASED ON HEATING SURFACE


Pounds of Steam/(hr ft2)

Firetube WatertubeType of Surface Boilers Boilers

Boiler heating surfaceHand fired 5 6Stoker fired 7 8Oil, gas, or pulverized fuel fired 8 10

Waterwall heating surfaceHand fired 8 8Stoker fired 10 12Oil, gas, or pulverized fuel fired 14 16

SI Units

Kilograms of Steam/(hr m2)

Firetube WatertubeType of Surface Boilers Boilers

Boiler heating surfaceHand fired 24 29Stoker fired 34 39Oil, gas, or pulverized fuel fired 39 49

Waterwall heating surfaceHand fired 39 39Stoker fired 49 59Oil, gas, or pulverized fuel fired 68 78

GENERAL NOTE: When a boiler is fired only by a gas having aheat value not in excess of 200 Btu/ft3 (2 000 Whr/m3), the minimumpressure relief valve relieving capacity may be based on the values givenfor hand-fired boilers above.

gram per hour per square meter) of boiler heating surfaceand waterwall heating surface, as given in Table A-44.

In many cases, a greater relieving capacity of pressurerelief valves will have to be provided than that estimatedusing Table A-44, in order to meet the requirements of thefirst paragraph of PG-67.2.

A-45

When boilers of different maximum allowable workingpressures with minimum pressure relief valve settings vary-ing more than 6% are so connected that steam can flowtoward the lower pressure units, the latter shall be protectedby additional pressure relief valve capacity, if necessary,on the lower pressure side of the system. The additionalsafety valve capacity shall be based upon the maximumamount of steam that can flow into the lower pressuresystem. The additional pressure relief valves shall have atleast one valve set at a pressure not to exceed the lowest

184

allowable pressure and the other valves shall be set withina range not to exceed 3% above that pressure.

A-46

If the pressure relief valve capacity cannot be determinedor if it is desirable to verify the computations, the capacitymay be checked in one of the three following ways, andif found insufficient, additional capacity shall be provided.

A-46.1 By making an accumulation test, that is, byshutting off all other steam-discharge outlets from theboiler and forcing the fires to the maximum. The pressurerelief valve equipment shall be sufficient to prevent anexcess pressure beyond that specified in PG-67.2. Thismethod should not be used on a boiler with a superheateror reheater or on a high-temperature water boiler.

A-46.2 By measuring the maximum amount of fuelthat can be burned and computing the corresponding evapo-rative capacity upon the basis of the heating value of thefuel (see A-12 through A-17).

A-46.3 By determining the maximum evaporativecapacity by measuring the feedwater. The sum of the pres-sure relief valve capacities marked on the valves shall beequal to or greater than the maximum evaporative capacityof the boiler. This method shall not be used on high-temperature water boilers.

A-48

When operating conditions are changed, or additionalheating surface such as water screens or waterwalls isconnected to the boiler circulation, the pressure relief valvecapacity shall be increased, if necessary, to meet the newconditions and be in accordance with PG-67.2. The addi-tional valves required on account of changed conditionsmay be installed on the piping between the boiler and themain stop valve except when the boiler is equipped witha superheater or other piece of apparatus. In the latter casethey may be installed on the piping between the boilerdrum and the inlet to the superheater or other apparatus,provided that the piping between the boiler and pressurerelief valve (or valves) connection has a cross-sectionalarea of at least three times the combined areas of the inletconnections to the pressure relief valves applied to it.

A-63A-63.2 During a hydrostatic test of a boiler, the safety

valve or valves shall be removed or each valve disk shallbe held to its seat by means of a testing clamp and not byscrewing down the compression screw upon the spring.



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2010 SECTION I

FIG. A-66 EXAMPLE FOR TYPICAL NOZZLE COMPUTATIONS

2 in.

5/8 in. 5/8 in.

3/4 in.

3/8 in.

41/4 in. dia

51/4 in. O.D. Lip

Limits of reinforcements

48 in

. in

sid

e d

iam

eter

vess

el

3 in. NPT

WL1 = 3/8 in.

WL3 = 3/8 in.

31/2 in.

GENERAL NOTE: This example was performed using computer software. The example was generated by performing the entire calculationwithout rounding off during each step. Accuracy of the final results beyond three significant figures is not intended or required.

A-64 REPAIRS TO EXISTING BOILERS

Where repairs are necessary that in any way affect theworking pressure or safety of a boiler, a state inspector,municipal inspector, or an inspector employed regularlyby an insurance company, which is authorized to do aboiler insurance business in the state in which the boileris used, shall be called for consultation and advice as tothe best method of making such repairs; after such repairsare made they shall be subject to the approval of a stateinspector, municipal inspector, or an inspector regularlyemployed by an insurance company that is authorized todo a boiler insurance business in the state in which theboiler is used.

EXAMPLES OF METHODS OFCOMPUTATION OF OPENINGS IN

VESSEL SHELLS

Application of the rules in PG-32, PG-33, PG-36 throughPG-39, PW-15, and PW-16 are given in the followingexamples. Common assumptions in all the examples arethat the design temperature corresponds to the temperatureof saturated steam at the maximum allowable workingpressure, that all areas are expressed in terms of equivalentarea of the vessel material (see PG-37), that thecorrosion/erosion allowance is zero, and that all openingsare single openings unless otherwise noted. Subscripts havebeen provided where necessary to eliminate confusionwhere an algebraic value has more than one meaning asused in these examples. (Sn denotes allowable stress of thenozzle material, Sv denotes allowable stress of the vesselmaterial, Rn denotes radius of nozzle, etc.) The values tand tn are assumed to be minimum in these examples.

185

A-65

A boiler shell, designed for 595 psig maximum allowableworking pressure, has an inside diameter of 36 in. and ismade of 1⁄2 in. thick plate. Is it permissible to install anNPS 2 (DN 50) connection by tapping a hole for the pipedirectly into the shell?

The NPS 2 (DN 50) connection complies with the pres-sure-size limitations in PG-39.5.2 and qualifies for theexception provided in PG-32.1.3.1 permitting the openingwithout requiring a calculation to determine the availabilityof compensation in the shell. PG-39.5.1 and Table PG-39,however, require a minimum plate thickness and threadengagement greater than that provided by the shell thick-ness. Therefore, the connection cannot be made as origi-nally stated; however, either a heavier shell plate or a built-up pad or properly attached plate or fitting could be usedto provide the minimum metal thickness and number ofthreads as required by PG-39 and Table PG-39. Should aplate or fitting, attached by welding, be used, the rules inPG-37, PW-15, and PW-16 shall be met.

A-66

A forged steel fitting as shown in Fig. A-66, with afemale 3 in. nominal pipe thread over the full fitting depth isto be inserted and welded into a vessel shell. The maximumallowable stress is 15,000 psi for the fitting material and17,500 psi for the vessel shell material. The maximumallowable working pressure of the vessel is 375 psig. SeeFig. A-66 for nozzle and vessel dimensions.

The fitting complies with the size, pressure, and threaddepth limitations provided in PG-39.5 and Table PG-39.The welded attachment does not qualify for the exceptionthat exempts the design from calculation of the required



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2010 SECTION I

reinforcement as provided in PG-32 and must, therefore,comply with PG-33 as follows:

Minimum required thickness for reinforcement consider-ation

Rv, the inside radius of the vessel p482

p 24 in.

Shell tr pPRv

Sv − (1 − y)P

p375 � 24

17,500 − (1 − 0.4) � 375

p 0.521 in.

Nozzle trn pPRn

Sn − (1 − y)P

p375 � 1.75

15,000 − (1 − 0.4) � 375

p 0.044 in.

Area of reinforcement required (see PG-33.3 and Fig.PG-33.1)

A p (d + 2tn) tr F

p (3.5 + 2 � 0.375) � 0.521 � 1.0

p 2.214 in.2

Area of reinforcement available in vessel wall (seePG-33.3, PG-36.4.1, and Fig. PG-33.1)

A1p (d − 2tn)(t − Ftr)

p (3.5 − 2 � 0.375)(0.625 − 1.0 � 0.521)

p 0.286 in.2

Area of reinforcement available in the nozzle wall externalof the vessel (see PG-33.3, PG-36.4.2, and Fig. PG-33.1)

In that the actual nozzle projection is less than thatpermitted within the limits of reinforcement, modificationof the equation provided in PG-33.1 will be required toreflect the actual area available for reinforcement.

A2 p 2(tn − trn)(actual projection) (Sn / Sv)

p 2 � (0.375 − 0.044) � 0.625 � (15,000 / 17,500)

p 0.354 in.2

Area of reinforcement available in the nozzle and nozzlelip internal of the vessel (see PG-33.3, PG-36.4.2, andFig. PG-33.1). Due to the nozzle lip, modification of theequation provided in Fig. PG-33.1 will be required to reflectthe actual area present.

186

A3 p 2tn tr1h + area present in lip

p 2 � 0.375 (15,000/17,500)(1.375)+ 2 � 0.5 � 0.75

p 1.634 in.2

Area of reinforcement available in attachment welds (seePG-36.4.3 and Fig. PG-33.1)

A4p (WL12 + WL2

2) (Sn / Sv)

p (0.3752 + 0.3752) (15,000 / 17,500)

p 0.241 in.2

Total area of reinforcement available

A1 + A2 + A3 + A41+ A43

p 2.515 in.2 ≥ A

as required for demonstration of compliance with PG-33.

Compliance with PG-37 and PW-15 is demonstrated bythe following calculations:

Required minimum strength to be provided by the welds(see PG-37 and PW-15)

W p (A − A1) Sv

p (2.214 − 0.286) 17,500

p 33,742 lb

Strength of the welds (see PG-37 and PW-15)

Internal fillet weld in shear

p 1⁄2 � WL3 (O.D. lip + WL3) (factor in PW-15.2) Sn

p 1⁄2 � 3.142 � 0.375 � (5.25 + 0.375) � 0.49 � 15,000

p 24,353 lb

External fillet weld in shear

p 1⁄2 �WL1 (dl + WL1) (factor in PW-15.2) Sn

p 0.5 � 3.142 � 0.375 � (4.25 + 0.375)� 0.49 � 15,000

p 20,027 lb

The combined strength of the welds equals 44,384 lb ≥ Was required for compliance with PG-37 and PW-15.

Verification of the minimum weld sizing as required byPW-16.1 and Fig. PW-16.1, illustration (u-2), is demon-strated by the following:

Required per Fig. PW-16.1, illustration (u-2)

t1 + t2 ≥ 1.25 tmin

t1 ≥ 0.25

t2 ≥ 0.25



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2010 SECTION I

Actual per Fig. A-66

t1 p WL1 sin 45°

p 0.375 � 0.7071

p 0.265 in.

t2 p WL2 sin 45°

p 0.375 � 0.7071

p 0.265 in.

tmin p 0.375 (based on tn)

Verification

(t1 + t2 p 0.530) ≥ (1.25 tmin p 0.469)

(t1 p 0.265) ≥ 0.25

(t2 p 0.265) ≥ 0.25

As verified by the above demonstrations, the design isproved to be in compliance with the requirements of Sec-tion I.

A-67

A vessel shell has a studding outlet connection mountedas shown in Fig. A-67. The maximum allowable stress ofboth the vessel and studding outlet material is 12,500 psi.The maximum allowable working pressure of the designis 325 psig. See Fig. A-67 for vessel and studding outletdimensions.

The studding outlet conforms to the requirements ofPG-39.4, both in arrangement and in tapped stud holerequirements. The welded attachment does not qualify forthe exception provided in PG-32 and must therefore com-ply with PG-33 as follows:


Shell tr pPRv

Sv − (1 − y) P

p325 � 30

12,500 − (1 − 0.4) � 325

p 0.792 in.

Nozzle trn p 0.0 [see Fig. PG-36.4, illustration (a)]

Area of reinforcement required (see PG-33.2)

A p tr Fd

p 0.79236 � 1.0 � 7.5

p 5.943 in.2

187

Area of reinforcement available in the vessel wall (seePG-36.4.1)

A1 p (t − Ftr) d

p (1.0 − 1.0 � 0.79236) � 7.5

p 1.557 in.2

Area of reinforcement available in attachment welds (seePG-36.4.3)

A4 p WL12 + WL3

p 0.5312 + 0.752

p 0.845 in.2

Area of reinforcement available in pad (see PG-36.4.3)

A5 p (O.D.pad − I.D.pad) te

p (12.5 − 6) � 1.5

p 9.75 in.2

Total area of reinforcement available

A1 + A4 + A5 p 12.152 in.2 ≥ A

as required for demonstration of compliance with PG-33.Compliance with PG-37 and PW-15 is demonstrated by

the following calculations:

Required minimum strength to be provided by the welds(see PG-37 and PW-15)

W p (A − A1) Sv

p (5.943 − 1.557) � 12,500

p 54,818 lb

Strength of the welds (see PG-37 and PW-15)

External fillet weld in shear

p 1⁄2 � WL1 (O.D.pad + WL1) (factor in PW-15.2) S

p 0.5 � 3.14159 � 0.53125 � (12.5 + 0.53125)� 0.49 � 12,500

p 66,606 lb

Internal fillet weld in shear

p 1⁄2 � WL3 (dl − WL3) (factor in PW-15.2) S

p 0.5 � 3.142 � 0.75 � (7.5 − 0.75)� 0.49 � 12,500

p 48,707 lb

The combined strength of the welds equals 115,313 lb ≥W as required for compliance with PG-37 and PW-15.



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2010 SECTION I


7/8 in. 9 Thd./in. Class 2B fit by 15/16 in. tapped depth

11/2 in. (te)

1 in.

6 in.

60 in

.in

sid

e d

iam

eter

121/2 in.

71/2 in.WL3 = 3/4 in.

WL1 = 17/32

in.

15 in. limit of reinforcement

vess

el

GENERAL NOTES:(a) Stud holes are staggered about the line of the longitudinal section and are shown for clarification only.(b) This example was performed using computer software. The example was generated by performing the entire calculation without rounding off

during each step. Accuracy of the final results beyond three significant figures is not intended or required.

Verification of the minimum weld sizing as required byPW-16.1 and Fig. PW-16.1, illustration (t) is demonstratedby the following:

Required per Fig. PW-16.1, illustration (t)

External fillet weld throat ≥ 1⁄2t min

Internal fillet weld throat ≥ 0.7t min


External fillet weld throat

p WL1 sin 45°p 0.531 � 0.707p 0.376 in.

Internal fillet weld throat

p WL3 sin 45°p 0.75 � 0.707p 0.530 in.

tmin p 0.75 (based on PW-16.2)

Verification

(External fillet weld throat p 0.376)

≥ (1⁄2 t min p 0.375)

188

(Internal fillet weld throat p 0.530)

≥ (0.7 t min p 0.525)

As verified by the above demonstrations, the design isproved to be in compliance with the requirements of Sec-tion I.

A-68

A boiler has an NPS 4 extra-strong pipe connectionmounted as shown in Fig. A-68. The maximum allowablestress is 12,000 psi for the pipe material and 13,700 psi forthe boiler shell material. The maximum allowable workingpressure of the boiler is 250 psig. See Fig. A-68 for pipeand shell dimensions.

Check to determine if the welded attachment qualifiesfor the exception provided in PG-32.

K pPD

1.82 St[see PG-32.1.2, eq. (2)]

p250 � 30.875

1.82 � 13,700 � 0.4375

p 0.7076 or 70.76%

Dt p 30.875 � 0.4375



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I


4.5 in.0.29487 in. min. [See PG-27.3 and PG-27.4 Note (7)]

3.826 in.

7.652 in. limit of reinforcement

Limit of reinforcement

Wd = 1/4 in.

7/16 in.

WL1 = 3/8 in. 0.73717 in.

30 in

.in

sid

e d

iam

eter

vess

el

45 deg

4 in. extra strong pipe

p 13.5078

From Fig. PG-32, maximum size of opening with inherentcompensation is 4.35 in.

Nominal I.D. of NPS 4 extra strong pipe is

4.5 − 2(0.337) p 3.826 in.

Since I.D. is less than maximum size opening from Fig. PG-32, no calculation need be made to demonstrate compliancewith the compensation requirements of PG-33 (seePG-32.1.3.2).

A-69

A vessel has a series of welded connections in a definitepattern as shown in Fig. A-69. The maximum allowablestress of all nozzle and vessel material is 17,500 psi. Themaximum allowable working pressure of the design is1,500 psig. See Fig. A-69 for all nozzle and vessel dimen-sions.

The welded attachments do not qualify for the exceptionprovided in PG-32 and must therefore comply with PG-33as follows:


Shell tr pPRv

Sv − (1 − y) P

p1,500 � 30

17,500 − (1 − 0.4) � 1500

189

p 2.711 in.

Nozzle trn 1 and 4 pP (0.5 dl1 − tn1)Sn − (1 − y) P

p1,500 (0.5 � 4.5 − 0.875)17,500 − (1 − 0.4) � 1500

p 0.124 in.

Nozzle trn 2 and 3 pP (0.5 dl2 − tn2)Sn − (1 − y) P

p1,500(0.5 � 5 − 1.0)

17,500 − (1 − 0.4) � 1500

p 0.136 in.

Check for overlapping limits

The sum of the limits of reinforcement on the longitudinalaxis between nozzles 1 and 2, as permitted underPG-36.2.2, is

p �d1

2+ tn1 + t� + �d2

2+ tn 2 + t�

p2.75

2+ 0.875 + 3.25 +

3.02

+ 1.0 + 3.25

p 11.25 in. > D1



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

2010 SECTION I


WL4 = 1/2 in.

WL3 = 11/4 in.

WL1 = 11/8 in.

tn1 = 7/8 in.

D1 = 9 in.

dl2 = 5 in.

dl3 = 5 in.

D1 = 9 in.

dl1 = 41/2 in.

dl4 = 41/2 in. dl4 = 41/2 in.

D 3 = 8

1 / 4 in.

dl1 = 41/2 in.

D2 = 61/2 in.

21/2 in. (2.5 tn2)

WL2 = 1/2 in.

3/4 in. 3/4 in.

t = 31/4 in.

60 in

.in

sid

e d

iam

eter

vess

el

23/16 in. (2.5 tn1)

D1 = 9 in.

dl1 = 41/2 in.

tn2 = 1 in.

dl2 = 5 in.

Longitudinal

line

No. 1No. 2

No. 4No. 4

No. 1

No. 3


No

zzle

No

. 2

No

zzle

No

. 1

C LC L

30 deg 30 deg

Wd1 = 1 in.

Wd2 = 1 in.

Wd4 = 11/4 in.

Wd3 = 11/4 in.

d1 = 2.75 in. d2 = 3.0 in.

+ tn2 + t = 5.75 in.d22

D1 x = 4.304 in.d1

d1 + d2D1 x = 4.695 in.

d2d1 + d2

+ tn1 + t = 5.5 in.d12

GENERAL NOTES:(a) Nozzles 1 and 4 are identical dimensionally and nozzles 2 and 3 are identical dimensionally.(b) This example was performed using computer software. The example was generated by performing the entire calculation without rounding off

during each step. Accuracy of the final results beyond three significant figures is not intended or required.

190



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2010 SECTION I

The sum of the limits of reinforcement on the circumferen-tial axis between nozzles 2 and 3 is

p �d2

2+ tn2 + t� + �d3

2+ tn3 + t�

p3.02

+ 1.0 + 3.25 +3.02

+ 1.0 + 3.25

p 11.5 in. > D2

The sum of the limits of reinforcement on the diagonalbetween nozzles 3 and 4 is

p �d3

2+ tn3 + t� + �d4

2+ tn4 + t�

p3.02

+ 1.0 + 3.25 +2.75

2+ 0.875 + 3.25

p 11.25 in. > D3

Each of the above conditions is greater than the center-to-center distance, for the condition considered, between theopenings; therefore, the limits of reinforcement overlapand the rule of PG-38.1 shall apply.

Nozzles 1 and 4 — area of reinforcement required in thelongitudinal plane

Al 1 p (d1 + 2tn1) trF

p (2.75 + 2 � 0.875) � 2.711 � 1.0

p 12.199 in.2

Nozzles 2 and 3 — area of reinforcement required in thelongitudinal plane

Al 2 p (d2 + 2 tn2) trF

p (3.0 + 2 � 1.0) � 2.711 � 1.0

p 13.554 in.2

Nozzles 2 and 3 — area of reinforcement required in thecircumferential plane

Ac2 p (d2 + 2tn2) trF

p (3.0 + 2 � 1.0) � 2.711 � 0.5

p 6.777 in.2

Nozzle 3 — area of reinforcement required in the diago-nal plane

Ad3 p (d3 + 2tn3) trF

p (3.0 + 2 � 1.0) � 2.711 � 0.88

191

p 11.928 in.2

Nozzle 4 — area of reinforcement required in the diago-nal plane

Ad4 p (d4 + 2tn4) trF

p (2.75 + 2 � 0.875) � 2.711 � 0.88

p 10.735 in.2

Area of reinforcement provided in nozzle 1 in the longitudi-nal plane

Due to the overlapping limits of reinforcement, the equa-tion for A1 (given in Fig. PG-33.1) will require modifica-tion. To prevent any reinforcement available between thenozzles from being counted more than once, the reinforce-ment limit is reduced such that the available reinforcementin the shell is divided and attributed to either nozzle’scompensation in proportion to its relative size. For nozzle1, this limit is D1 [d1/ (d1 + d2)]. The limit on the otherside remains unchanged as d1/2 + tn1 + t.

A1 p t + D1 [d1/ (d1 + d2)] −dl12 �(t − Ftr)

p 3.25 + 9 [2.75/ (2.75 + 3.0)] − 4.5/2�� (3.25 − 1.0 � 2.711)

p 2.860 in.2

A2 p 2 (tn1 − trn1) 2.5 tn1

p 2 (0.875 − 0.12424) � 2.5 � 0.875

p 3.285 in.2

A3 p 2 tn1h

p 2 � 0.875 � 4.0

p 7.0 in.2

A41+ A43

p WL12 + WL2

2

p 1.1252 + 0.52

p 1.516 in.2

Total area of available reinforcement provided by nozzle1 in the longitudinal plane

A1 + A2 + A3 + A41+ A43

p 14.660 in.2 ≥ Al1


Area of reinforcement provided in nozzle 2 in the longitudi-nal plane



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2010 SECTION I

Since nozzle 2 has its limits of reinforcement restricted onboth sides by nozzle 1, the reduced limit of D1 [d2/(d1 + d2)]is applicable to both sides.

A1 p 2 � D1 [d2/(d1 + d2)] − dl2� (t − Ftr)

p2 � 9 [3.0/(2.75 + 3.0)] − 5.0�� (3.25 − 1.0 � 2.711)

p 2.368 in.2

A2 p 2 (tn2 − trn2) 2.5tn2

p 2 (1.0 − 0.136) � 2.5 � 1.0

p 4.322 in.2

A3 p 2tn2h

p 2 � 1.0 � 4.0

p 8.0 in.2

A4 p WL32 + WL4

2

p 1.252 + 0.52

p 1.812 in.2

Total area of available reinforcement provided by nozzle2 in the longitudinal plane

A1 + A2 + A3 + A4 p 16.502 in.2 ≥ Al 2


Area of reinforcement provided in nozzle 2 or 3 in thecircumferential plane

A1 p t + D2 [d2/(d2 + d3)] −dl22 � (t − Ftr)

p 3.25 + 6.5 [3.0/(3.0 + 3.0)] −5.02 �

� (3.25 − 0.5 � 2.711)

p 7.578 in.2

A2 p 2 (tn2 − trn2) 2.5tn2

p 2 (1.0 − 0.13554) � 2.5 � 1.0

p 4.3223 in.2

A3 p 2 tn2h

p 2 � 1.0 � 4.0

p 8.0 in.2

A4 p WL32 + WL4

2

p 1.252 + 0.52

192

p 1.8125 in.2

Total area of available reinforcement provided by nozzle2 or 3 in the circumferential plane

A1 + A2 + A3 + A4 p 21.713 in.2 ≥ Ac2


Area of reinforcement provided by nozzle 3 in the diago-nal plane

Although nozzle 1 does not lie exactly in the same planeas nozzles 3 and 4 and is slightly farther away, for simplic-ity the limit on both sides of nozzle 3 are restricted to thereduced limit between nozzles 3 and 4.

A1 p 2 � D3 � [d3/(d3 + d4)] − dl3� (t − Ftr)

p 2 � 8.25 � [3.0/(3.0 + 2.75)] − 5.0�� (3.25 − 0.88 � 2.711)

p 3.120 in.2

A2 p 2 (tn3 − trn3) 2.5tn3

p 2 (1.0 − 0.136) � 2.5 � 1.0

p 4.322 in.2

A3 p 2 tn3 h

p 2 � 1.0 � 4.0

p 8.0 in.2

A41+ A43

p WL 32 + WL4

2p 1.252 + 0.52

p 1.812 in.2

Total area of available reinforcement provided by nozzle3 in the diagonal plane

A1 + A2 + A3 + A41+ A43

p 17.254 in.2 ≥ Ad3


Area of reinforcement provided in nozzle 4 in the diago-nal plane

A1 p t + D3 � [d4/(d4 + d3)] −dl42 � (t − Ftr)

p 3.25 + 8.25 � [2.75/(2.75 + 3.0)] −4.52 �

� (3.25 − 0.88 � 2.711)

p 4.275 in.2

A2 p 2 (tn4 − trn4) 2.5 tn4

p 2 (0.875 − 0.124) � 2.5 � 0.875



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2010 SECTION I

p 3.285 in.2

A3 p 2 tn4 h

p 2 � 0.875 � 4.0

p 7.0 in.2

A4 p WL 32 + WL4

2

p 1.252 + 0.52

p 1.516 in.2

Total area of available reinforcement provided by nozzle4 in the diagonal plane

A1 + A2 + A3 + A4 p 16.076 in.2 ≥ Ad4


The rule of PG-38.4 for the minimum required net cross-sectional area between any two finished openings shallapply as follows:

Net area required in longitudinal plane between nozzles 1and 2

nar p 0.7 Ftr D1

p 0.7 � 1.0 � 2.711 � 9

p 17.078 in.2

Net area provided in vessel wall

nav p [D1 − 0.5 (dl1 + dl2)] t

p [9 − 0.5 � (4.5 + 5)] � 3.25

p 13.812 in.2

Net area provided in nozzle wall fused to vessel wall

nan p tn1Wd1 + tn1Wd2 + tn2Wd3 + tn2Wd4

p 0.875 � 1.0 + 0.875 � 1.0 + 1.0 � 1.25 + 1.0 � 1.25p 4.25 in.2

Total net area provided in the longitudinal plane betweennozzles 1 and 2

nav + nan p 18.0625 in.2 ≥ nar as required for demonstrationof compliance with PG-38.4

Net area required in the circumferential plane betweennozzles 2 and 3

nar p 0.7 Ftr D2

p 0.7 � 0.5 � 2.711 � 6.5

p 6.167 in.2


193

nav p [D2 − 0.5 (dl2 + dl3)]t

p [6.5 − 0.5 � (5 + 5)] � 3.25

p 4.875 in.2

Net area provided in the nozzle wall fused to the vessel wall

nan p Ttn2 Wd3 + tn2 Wd4 + tn3 Wd3 + tn3 Wd4

p 1.0 � 1.25 + 1.0 � 1.25 + 1.0 � 1.25 + 1.0 � 1.25p 5 in.2

Total net area provided in the circumferential planebetween nozzles 2 and 3

nav + nan p 9.875 in.2 ≥ nar as required for demonstra-tion of compliance with PG-38.4

Net area required in the diagonal plane between nozzles3 and 4

nar p 0.7 Ftr D3

p 0.7 � 0.88 � 2.711 � 8.25

p 13.776 in.2


nav p [D3 − 0.5 (dl3 + dl4)] t

p [8.25 − 0.5 � (5 + 4.5)] � 3.25

p 11.375 in.2

Net area provided in the nozzle wall fused to the vessel wall

nan p tn3 Wd3 + tn3 Wd4 + tn4 Wd1 + tn4 Wd2

p 1.0 � 1.25 + 1.0 � 1.25 + 0.875 � 1.0+ 0.875 � 1.0

p 4.25 in.2

Total net area provided in the diagonal plane betweennozzles 3 and 4

nav + nan p 15.625 in.2 ≥ nar as required for demon-stration of compliance with PG-38.4

Nozzles 1 and 4 — The required minimum strength to beprovided by the combined load-carrying elements througheach load-carrying path (see PG-37 and PW-15)

W p (A − A1) Sv

p (12.199 − 2.860) � 17,500

p 163,431 lb

Strength of the welds

Fillet welds in shear

p1⁄2 � � (WL1 + WL2) dl1 (factor in PW-15.2) S



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2010 SECTION I

p0.5 � 3.142 � (1.125 + 0.5) � 4.5 � 0.49 � 17,500

p98,495 lb

Groove welds in tension

p1⁄2 � (Wd1 + Wd2) dl1 (factor in PW-15.2) S

p0.5 � 3.142 � (1.0 + 1.0) � 4.5 � 0.74 � 17,500

p183,076 lb

The combined strength equals 281,571 lb ≥ W as requiredfor demonstration of compliance with PG-37 and PW-15.

Nozzles 2 and 3 — The required minimum strength ofthe welds (see PG-37 and PW-15)

W p (A − A1) Sv

p (13.544 − 2.368) � 17,500p 195,766 lb

Strength of the welds

Fillet welds in shear

p1⁄2 � (WL3 + WL4)dl2(factor in PW-15.2) S

p0.5 � 3.142 � (1.25 + 0.5) � 5 � 0.49 � 17,500

p117,859 lb

Groove welds in tension

p1⁄2 � (Wd3 + Wd4)dl2(factor in PW-15.2)S

p0.5 � 3.142 � (1.25 + 1.25) � 5 � 0.74 � 17,500

p254,273 lb

The combined strength of path number 3 equals 372,132lb ≥ W as required for demonstration of compliance withPG-37 and PW-15.

Nozzles 1 and 4 — Verification of minimum weld sizingas required by PW-16.1 and Fig. PW-16.1, illustration (f)

Required per Fig. PW-16.1, illustration (f)

t1 + t2 ≥ 1.25tmin

tc ≥ 0.25

t1 ≥ 0.25

t2 ≥ 0.25


tc p WL2 sin 45°

194

p 0.5 � 0.7071

p 0.354 in.

tmin p 0.75 in. (based on PW-16.2)

t1 p WL1 sin 45°

p 1.125 � 0.707

p 0.795 in.

t2 p Wd1 + Wd2

p 1.0 + 1.0

p 2 in.

Verification

(t1 + t2 p 2.795) ≥ (1.25tmin p 0.937)

(tc p 0.354) ≥ 0.25

(t1 p 0.795) ≥ 0.25

(t2 p 2) ≥ 0.25

Nozzles 2 and 3 — Verification of minimum weld sizingas required by PW-16.1 and Fig. PW-16.1, illustration (f)

Required per Fig. PW-16.1, illustration (f)

t1 + t2 ≥ 1.25tmin

tc ≥ 0.25

t1 ≥ 0.25

t2 ≥ 0.25


tc p WL4 sin 45°

p 0.5 � 0.707

p 0.354

tmin p 0.75 in. (based on PW-16.2)

t1 p WL3 sin 45°

p 1.25 � 0.7071

p 0.884 in.

t2 p Wd3 + Wd4

p 1.25 + 1.25

p 2.5 in.



--``,`,`,`,,,,```,,,,,,,,`,,`,``-`-`,,`,,`,`,,`---

(10)

2010 SECTION I

Verification

(t1 + t2 p 3.384) ≥ (1.25tmin p 0.937)

(tc p 0.354) ≥ 0.25

(t1 p 0.884) ≥ 0.25

(t2 p 2.5) ≥ 0.25

As verified by the above demonstrations, the design isproved to be in compliance with the requirements ofSection I.

A-70

A vessel constructed of SA-387 Grade 91 Class 2 platewith a longitudinal weld seam has an SA-335 P91 NPS 4XXS pipe nozzle attached as shown in Fig. A-70. Themaximum allowable working pressure is 1,900 psig at1,000°F. The maximum allowable stress is 16,300 psi forboth the vessel and the pipe connection. The vessel hasreceived subcritical PWHT in accordance with PW-39after welding. The vessel does not qualify for the excep-tion in PG-32 and therefore must comply with PG-26,PG-27, and PG-33.

From Table PG-26, the weld strength reduction factorfor CSEF (Sub Crit) at 1,000°F is w p 0.5. As indicatedin PG-27.4, Note 1, E p w. From PG-27.4, Note 6, y p0.7. From PG-27.4, Note 3, C p 0.

Shell t pPD

2SE + 2yP+ C

p1,900 � 18

2 � 16,300 � 0.5 + 2 � 0.7 � 1,900+ 0

p 1.804 in.

The thickness of the vessel is greater than 1.804 in.and therefore satisfies the requirements of PG-26 andPG-27.


Shell tr pPD

2SE + 2yP+ C

p1,900 � 18

2 � 16,300 � 1.0 + 2 � 0.7 � 1,900+ 0

p 0.970 in.

Nozzle trn pPR

SE − (1 − y)P+ C

p1,900 � 1.576

2 � 16,300 � 1 − (1 − 0.7) 1,900+ 0

195

p 0.190 in.

Area of reinforcement required in the longitudinal plane

A p dtr F

p 3.152 � 0.970 � 1

p 3.057 in.2

Limit of reinforcement parallel to the vessel wall is thegreater of

d or Rn + tn + t p 1.576 + 0.674 + 2

p 4.25 in.

Limit of reinforcement normal to the vessel wall is thesmaller of

21/2 t or 21/2 tn + te p 2.5 � 0.674 + 0

p 1.685 in.

Area of reinforcement available

A1p 2(t + tn) (t − Ftr)

p 2 (2 + 0.674) (2 − 1 � 0.970)

p 5.509 in.2

A2p 2(tn − trn) (21/2 tn + te) fr1

p 2 (0.670 − 0.190) (21/2 � 0.674 + 0 ) 1

p 1.630 in.2

A41p (WL1)2 fr2

p 0.3752

p 0.140 in.2

Total area available for reinforcement

p A1 p A2 p A41 p 7.279 ≥ 3.057

therefore the opening is adequately reinforced.

Verification of minimum weld size as required byPW-16.1 and Fig. PW-16.1, illustration (a).

Required per Fig. PW-16.1, illustration (a), tc must begreater than the smaller of 1/4 in. or 0.7tmin.

tmin p 0.674 in.

0.7tmin p 0.472 in.

tc ≥ 0.25



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(10)

2010 SECTION I



2 in.

8.5 in.

18 in

. ou

tsid

e d

iam

eter

1.685 in.

3.152 in.

4.5 in.


tcp WL1 sin 45 deg

p 0.375 � 0.7071

p 0.265 > 0.255

therefore the weld size is adequate.

EXAMPLES OF COMPUTATION OFALLOWABLE LOADING ON

STRUCTURAL ATTACHMENTS TOTUBES

A-71

A tube is suspended by a welded attachment with theloads and dimensions as shown in Fig. A-71. This is acondition of direct radial loading on the tube.

The allowable lug loading is calculated for the follow-ing conditions:

196

D p 4 in.material p SA-213-T22MAWP p 2258 psi

T p 800°Ft p 0.30 in.

1⁄4 in. thick lug

7 deg attachment angle

S p 15,000 psiSa p 15,000 psiSt p 2.0 Sa − S p 15,000 psi

From Table PW-43.1, K p 1.07

From Fig. PW-43.1 or PW-43.2.1 or PW-43.2.2

X p D/t2 p 44.4

Compression Lf p 0.0326Tension Lf p 0.0405

La p K (Lf)S



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2010 SECTION I

FIGS. A-71–A-74 TYPES OF STRUCTURALATTACHMENTS TO TUBES

31/4 in. O.D. × 0.375 in.

11/2 in.

11/2 in.

3 in.

2 in.

1,500 lb

440 lb

750 lb1,200 lb

3 in. R

3/4 in.

11/4 in.

21/2 in.

FIG. A-71

4 in. O.D. × 0.300 in.

2 in. O.D. × 0.300 in.

11/8 in.

7/8 in.

4 in.

960 lb

FIG. A-72

FIG. A-74FIG. A-73

4 in. O.D. × 0.300 in.

2 in.

Compression La p (1.07)(0.0326)(15,000)p 523 lb/in.

Tension La p (1.07)(0.0405)(15,000)p 650 lb/in.

Actual load

W p 1,500 lb (Tension)

L p 1,500 lb/3 in. p 500 lb/in. < 650 lb/in.

The loading indicated is therefore within the valuesallowed by the chart in Fig. PW-43.1.

A-72

A load is supported on a rubbing strip welded to atube, as shown in Fig. A-72. This problem illustrates acondition where the load is not applied on the center ofwelded attachment.

The allowable lug loading is calculated for the sameconditions given in example A-71Compression La p (1.07)(0.0326)(15,000)

p 523 lb/in.Tension La p (1.07)(0.0405)(15,000)

p 650 lb/in.

197

Actual unit load

W p 960 lb

L p960

4±

(6 � 960 � 0.875)

42p 240 ± 315

p 555 lb/in. compression; 75 lb/in. tension

The actual loading does not exceed values of allowableloading.

A-73A-73.1 A load is supported from a vertical tube with

a welded bracket attachment as shown in Fig. A-73. Thisexample illustrates a condition of eccentric loading wherethe direct loading is not additive.


D p 3.25 in.material p SA-213-T22MAWP p 3722 psi

T p 800°Ft p 0.375 in.

1⁄4 in. thick lug




From Fig. PW-43.1, PW-43.2.1, or PW-43.2.2

X p D/t2 p 23.11

Compression Lf p 0.0637Tension Lf p 0.090

La p K (Lf)S

Compression La p (1.108)(0.0637)(15,000)p 1,058 lb/in.

Tension La p (1.108)(0.090)(15,000) p 1,495 lb/in.

Actual

W p 440 lb

L p6 � 440 � 1.5

22

p 990 lb/in. compression or tension



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2010 SECTION I

The actual loading does not exceed values of allowableloading.

A-73.2 To determine the maximum allowable loadingon structural attachments to tubes, a test may be con-ducted on a full-size section of tube with attachment. Thetest may be considered as meeting the Code requirementsprovided

A-73.2.1 The loading applied to the test specimenis at least equivalent to the design loading, and at thesame time the tube is subjected to a hydrostatic pressurecorresponding to design conditions.

A-73.2.2 The test is conducted in accordance withthe requirements of A-22 with the exception that thehydrostatic pressure shall be held at expected design pres-sure, and the loading on the support shall be increaseduntil permanent set occurs.

A-73.2.3 The maximum load P, allowed on theattachment at or below the pressure corresponding to thehydrostatic pressure, is given by the following equation:

P pHSE

where

E p average proportional limit of the tube mate-rial, psi

H p test load at the proportional limit of the struc-ture, lb

P p maximum allowable load on attachment, lbS p working stress permitted in Table 1A of Section

II, Part D, for the tube material at the designtemperature that in no case shall be taken at lessthan 700°F, psi

A-74

A superheater section is supported by welded attach-ment to the short-radius return bend section as shown inFig. A-74. This example illustrates a condition where adirect and eccentric load is applied to a bent tube section.


D p 2.0 in.material p SA-213-T22MAWP p 5,087 psi

T p 700°Ft p 0.30 in.

1⁄4 in. thick lug



198


From Fig. PW-43.1, PW-43.2.1, or PW-43.2.2

X p D/t2 p 22.2

Compression Lf p 0.0664Tension Lf p 0.0948For bend

X p (Bend dia)/t2 p 6/0.32 p 66.6

From Fig. PW-43.1 or eqs. PW-43.2.1 or PW-43.2.2Compression Lf p 0.0215Tension Lf p 0.0257

La p K(�Lf) St

Compression La p (1.16)(0.0664 + 0.0215)(15,000)p 1,529 lb/in.

Tension La p (1.16)(0.0948 + 0.0257)(15,000)p 2,096 lb/in.

Actual unit load

P p7502.5

±6 � 1,200 � 0.75

2.52

p 300 ± 864 p 1,164 lb/in. compression; 564lb/in. tension

The actual applied load is less than the values allowedby the chart in Fig. PW-43.1.

PREHEATING

A-100A-100.1 Preheating may be employed during welding

to assist in completion of the welded joint. The need forand the temperature of preheat are dependent on a numberof factors such as chemical analysis, degree of restraint ofthe parts being joined, elevated temperature mechanicalproperties, and material thicknesses. Mandatory rules forpreheating are, therefore, not given in this Section exceptas required in Table PW-39. As a general guide, someminimum temperatures for preheating are given inA-100.4. It is cautioned that the preheating temperatureslisted in A-100.4 do not necessarily ensure satisfactorycompletion of the welded joint. Requirements for individ-ual materials within the P-Number listing may have pre-heating requirements more or less restrictive than thisgeneral guide. The Welding Procedure Specification forthe material being welded shall specify the minimumpreheating requirements described in the welding proce-dure qualification requirements of Section IX.

A-100.2 The heat of welding may assist in main-taining preheat temperatures after the start of weldingand, for inspection purposes, temperature measurements



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2010 SECTION I

may be made near the weld. The method or extent ofapplication of preheat is not, therefore, specifically given.Normally, when materials of two different P-Numbergroups are joined by welding, the preheat used will bethat of the material with the higher preheat specified onthe Welding Procedure Specification.

A-100.3 Thicknesses referred to are nominal at theweld for the parts to be joined.

A-100.4 Minimum Temperatures for Preheating

A-100.4.1 P-No. 1, Group No. 1, 2, 3. 175°F(80°C) for material that has both a specified maximumcarbon content in excess of 0.30% and a thickness at thejoint in excess of 1 in. (25 mm); 50°F (10°C) for all othermaterials in this grouping.

A-100.4.2 P-No. 3, Group No. 1, 2, 3. 175°F(80°C) for material that has either a specified minimumtensile strength in excess of 70,000 psi (480 MPa) or athickness at the joint in excess of 5⁄8 in. (16 mm); 50°F(10°C) for all other materials in this grouping.

A-100.4.3 P-No. 4, Group No. 1, 2. 250°F (120°C)for material that has either a specified minimum tensilestrength in excess of 60,000 psi (410 MPa) or a thicknessat the joint in excess of 1⁄2 in. (13 mm); 50°F (10°C) forall other materials in this grouping.

A-100.4.4 P-No. 5A, Group No. 1 and P-No. 5B,Group No. 1. 400°F (205°C) for material that has either aspecified minimum tensile strength in excess of 60,000 psi(410 MPa) or has both a specified minimum chromiumcontent above 6.0% and a thickness at the joint in excessof 1⁄2 in. (13 mm); 300°F (150°C) for all other materialsin this grouping.

A-100.4.5 P-No. 6, Group No. 1, 2, 3. 400°F(205°C).

A-100.4.6 P-No. 7, Group No. 1, 2. None.

A-100.4.7 P-No. 8, Group No. 1, 2. None.

A-100.4.10 P-No. 10A, Group No. 1. 175°F(80°C).

A-100.4.11 P-No. 10I, Group No. 1. 300°F(150°C) with interpass maintained between 350°F and450°F (175°C and 230°C).

A-100.4.12 P-No. 15E, Group No. 1. 400°F(205°C) for material that has either a specified minimumtensile strength in excess of 60,000 psi (410 MPa) or hasboth a specified minimum chromium content above 6.0%and a thickness at the joint in excess of 1/2 in. (13 mm);300°F (150°C) for all other materials in this grouping.

199

MAXIMUM ALLOWABLE WORKINGPRESSURES — THICK SHELLS

A-125 SHELLS FOR INTERNALPRESSURE

When the thickness of the shell exceeds one-half ofthe inside radius, the required thickness and maximumallowable working pressure on the cylindrical shell ofa boiler or drum shall be determined by the followingequations:

t p (� Z1 − 1) R p �� Z1− 1

� Z1� Ro

or

P p SEZ2 − 1Z2 + 1

where


p ligament efficiency per PG-52 or PG-53 forseamless cylinders with ligaments

p w, the weld joint strength reduction factor perPG-26 for longitudinally welded cylinders with-out ligaments

For longitudinally welded cylinders with liga-ments located such that no part of the longitudi-nal weld seam is penetrated by the openingsforming the ligament, E shall be taken as thelesser of w or the ligament efficiency from PG-52 or PG-53. If any part of the longitudinal seamweld is penetrated by the openings that form theligaments, E shall be taken as the product of wtimes the ligament efficiency.

P p maximum allowable working pressureR p inside radius of the weakest course of the shell

Ro p outside radius of the weakest course of the shellS p maximum allowable working unit stress, taken

from Table 1A of Section II, Part Dt p minimum thickness of shell plates in weakest

coursew p weld joint strength reduction factor per PG-26Z1 p (SE + P) / (SE −P)Z2 p [(R + t) / R]2 p (Ro / R)2

NOTE: Restrictions of PG-27.2.2 also apply to this paragraph.

ROUNDED INDICATION CHARTSA-250 ACCEPTANCE STANDARD FOR

RADIOGRAPHICALLYDETERMINED ROUNDEDINDICATIONS IN WELDS

A-250.1 Applicability of These Standards. Thesestandards are applicable to ferritic, austenitic, and nonfer-rous materials.



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2010 SECTION I

A-250.2 TerminologyA-250.2.1 Rounded Indications. Indications with

a maximum length of three times the width or less onthe radiograph are defined as rounded indications. Theseindications may be circular, elliptical, conical, or irregularin shape and may have tails. When evaluating the sizeof an indication, the tail shall be included. The indicationmay be from any imperfection in the weld, such as poros-ity, slag, or tungsten.

A-250.2.2 Aligned Indications. A sequence of fouror more rounded indications shall be considered to bealigned when they touch a line parallel to the length of theweld drawn through the center of the two outer roundedindications.

A-250.2.3 Thickness t. t is the thickness of theweld, of the pressure–retaining material, or of the thinnerof the sections being joined, whichever is least. If a fullpenetration weld includes a fillet weld, the thickness ofthe fillet weld throat shall be included in t.

A-250.3 Acceptance CriteriaA-250.3.1 Image Density. Density within the

image of the indication may vary and is not a criterionfor acceptance or rejection.

A-250.3.2 Relevant Indications (See Table A-250.3.2 for Examples). Only those rounded indicationswhich exceed the following dimensions shall be consid-ered relevant:

(a) 1⁄10 t for t less than 1⁄8 in. (3 mm)(b) 1⁄64 in. (0.4 mm) for t 1⁄8 in. to 1⁄4 in. (6 mm), inclusive(c) 1⁄32 in. (0.8 mm) for t 1⁄4 in. (6 mm) to 2 in. (50 mm),

inclusive(d) 1⁄16 in. (1.6 mm) for t greater than 2 in. (50 mm)

A-250.3.3 Maximum Size of Rounded Indication(See Table A-250.3.2 for Examples). The maximumpermissible size of any indication shall be 1⁄4t, or 5⁄32 in.(4 mm), whichever is smaller; except that an isolatedindication separated from an adjacent indication by 1 in.(25 mm) or more may be 1⁄3t, or 1⁄4 in. (6 mm), whicheveris less. For t greater than 2 in. (50 mm) the maximumpermissible size of an isolated indication shall beincreased to 3⁄8 in. (10 mm).

A-250.3.4 Aligned Rounded Indications. Alignedrounded indications are acceptable when the summationof the diameters of the indications is less than t in a lengthof 12t (see Fig. A-250.3.4-1). The length of groups ofaligned rounded indications and the spacing between thegroups shall meet the requirements of Fig. A-250-3.4-2.

A-250.3.5 Spacing. The distance between adjacentrounded indications is not a factor in determining accept-ance or rejection, except as required for isolated indica-tions or groups of aligned indications.

200

TABLE A-250.3.2MAXIMUM PERMISSIBLE SIZE OF

ROUNDED INDICATION(Examples Only)


Maximum Size of Maximum SizeAcceptable Rounded of Nonrevelant

Indication, in.Thickness Indication,t, in. Random Isolated in.

Less than 1⁄81⁄4t

1⁄3t1⁄10t

1⁄8 0.031 0.042 0.0153⁄16 0.047 0.063 0.015

1⁄4 0.063 0.083 0.0155⁄16 0.078 0.104 0.031

3⁄8 0.091 0.125 0.0317⁄16 0.109 0.146 0.031

1⁄2 0.125 0.168 0.0319⁄16 0.142 0.188 0.031

5⁄8 0.156 0.210 0.03111⁄16 0.156 0.230 0.031

3⁄4 to 2 incl. 0.156 0.250 0.031Over 2 0.156 0.375 0.063

SI Units

Maximum Size of Maximum SizeAcceptable Rounded of Nonrevelant

Indication, mmThickness Indication,t, mm Random Isolated mm

Less than 3 1⁄4t1⁄3t

1⁄10t3 0.79 1.07 0.385 1.19 1.60 0.386 1.60 2.11 0.388 1.98 2.64 0.79

10 2.31 3.18 0.7911 2.77 3.71 0.7913 3.18 4.27 0.7914 3.61 4.78 0.7916 3.96 5.33 0.7917 3.96 5.84 0.79

19 to 50 incl. 3.96 6.35 0.79Over 50 3.96 9.53 1.60

A-250.3.6 Rounded Indication Charts. Therounded indications characterized as imperfections shallnot exceed that shown in the charts.

The charts in Figs. A-250.3.6-1 through A-250.3.6-6illustrate various types of assorted, randomly dispersed,and clustered rounded indications for different weld thick-nesses greater than 1⁄8 in. (3 mm). These charts representthe maximum acceptable concentration limits for roundedindications.

The chart for each thickness range represents full-scale6 in. (150 mm) radiographs, and shall not be enlarged orreduced. The distributions shown are not necessarily thepatterns that may appear on the radiograph, but are typicalof the concentration and size of indications permitted.



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2010 SECTION I

FIG

.A

-250

.3.4

.-1

AL

IGN

ED

RO

UN

DE

DIN

DIC

AT

ION

S

GE

NE

RA

L N

OT

E: S

um

of

L 1 to

Lx

shal

l be

less

th

an t

in a

len

gth

of

12 t

.

L 1

L 2

L x

201

FIG

.A-2

50.3

.4-2

GR

OUP

SOF

ALI

GN

ED

ROU

ND

ED

IND

ICA

TION

S

GE

NE

RA

L N

OT

E: S

um

of

the

gro

up

len

gth

s sh

all b

e le

ss t

han

t in

a le

ng

th o

f 12

t.

Max

imu

m G

rou

p L

eng

thL

= 1 /

4 in

. (6

mm

) fo

r t

less

th

an 3

/ 4 in

. (19

mm

)L

= 1 /

3 t

for

t 3 /

4 in

. (19

mm

) to

21 /

4 in

. (57

mm

)L

= 3 /

4 in

. (19

mm

) fo

r t

gre

ater

th

an 2

1 /4

in. (

57 m

m)

L 13L

23L

3L 3

L 43L

3

Min

imu

m G

rou

p S

pac

ing

3L w

her

e L

is t

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the

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eval

uat

ed.



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2010 SECTION I

FIG. A-250.3.6-1 CHARTS FOR t 1⁄8 in. (3 mm) TO 1⁄4 in. (6 mm), INCLUSIVE

GENERAL NOTE: Typical concentration and size permitted in any 6 in. (150 mm) length of weld

(a) Random Rounded Indications

(c) Cluster(b) Isolated Indication(Maximum size per Table A-250.3.2)

1 in. (25 mm) 1 in. (25 mm)

A-250.3.7 Weld Thickness t Less Than 1⁄8 in.(3 mm). For t less than 1⁄8 in. (3 mm), the maximumnumber of rounded indications shall not exceed 12 in a6 in. (150 mm) length of weld. A proportionally fewernumber of indications shall be permitted in welds lessthan 6 in. (150 mm) in length.

A-250.3.8 Clustered Indications. The illustrationsfor clustered indications show up to four times as manyindications in a local area, as that shown in the illustra-tions for random indications. The length of an acceptablecluster shall not exceed the lesser of 1 in. (25 mm) or2t. Where more than one cluster is present, the sum ofthe lengths of the clusters shall not exceed 1 in. (25 mm)in a 6 in. (150 mm) length of weld.

METHODS FOR MAGNETICPARTICLE EXAMINATION (MT)

A-260A-260.1 Scope. This Appendix provides for proce-

dures that shall be followed whenever magnetic particleexamination is required by PG-93. The detailed examina-tion method of Article 7 of Section V shall be usedwith the acceptance criteria specified in this Appendix.Magnetic particle examination shall be performed inaccordance with a written procedure, certified by theManufacturer to be in accordance with the requirementof T-150 of Section V.

A-260.2 Certification of Personnel. The Manufac-turer shall certify that each magnetic particle examinermeets the following requirements:

(a) The examiner has vision, with correction if neces-sary, to enable him to read a Jaeger Type No. 2 Standard

202

Chart at a distance of not less than 12 in. (300 mm) andis capable of distinguishing and differentiating contrastbetween colors used. These capabilities shall be checkedannually.

(b) The examiner is competent in the techniques ofthe magnetic particle examination method for which heis certified, including making the examination and inter-preting and evaluating the results, except that where theexamination method consists of more than one operation,he may be certified as being qualified only for one ormore of these operations.

A-260.3 Evaluation of Indications. Indications willbe revealed by retention of magnetic particles. All suchindications are not necessarily imperfections, however,since excessive surface roughness, magnetic permeabilityvariations (such as at the edge of heat affected zones),etc., may produce similar indications.

An indication of an imperfection may be larger thanthe imperfection that causes it; however, the size of theindication is the basis for acceptance evaluation. Onlyindications that have any dimension greater than 1⁄16 in.(1.5 mm) shall be considered relevant.

(a) A linear indication is one having a length greaterthan three times the width.

(b) A rounded indication is one of circular or ellipticalshape with a length equal to or less than three times itswidth.

(c) Any questionable or doubtful indications shall bereexamined to determine whether or not they are relevant.

A-260.4 Acceptance Standards. All surfaces to beexamined shall be free of

(a) relevant linear indications(b) relevant rounded indications greater than 3⁄16 in.

(5 mm)



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2010 SECTION I

(c) four or more relevant rounded indications in a lineseparated by 1⁄16 in. (1.5 mm) or less, edge to edge

METHODS FOR LIQUIDPENETRANT EXAMINATION (PT)

NOTE: Satisfactory application of this method of examination requiresspecial skills in the techniques involved and in interpreting the results.The requirements specified herein presume application by suitably expe-rienced personnel.

A-270A-270.1 Scope. This Appendix provides for proce-

dures that shall be followed whenever liquid penetrantexamination is required by PG-93. The detailed examina-tion method of Article 6 of Section V shall be used withthe acceptance criteria specified in this Appendix. Liquidpenetrant examination shall be performed in accordancewith a written procedure, certified by the Manufacturerto be in accordance with the requirement of T-150 ofSection V.

A-270.2 Certification of Personnel. The Manufac-turer shall certify that each liquid penetrant examinermeets the following requirements:

(a) The examiner has vision, with correction if neces-sary, to enable him to read a Jaeger Type No. 2 StandardChart at a distance of not less than 12 in. (300 mm) andis capable of distinguishing and differentiating contrastbetween colors used. These capabilities shall be checkedannually.

(b) The examiner is competent in the techniques ofthe liquid penetrant examination method for which he iscertified, including making the examination and interpret-ing and evaluating the results, except that where the exam-ination method consists of more than one operation, hemay be certified as being qualified only for one or moreof these operations.

A-270.3 Evaluation of Indications. An indication ofan imperfection may be larger than the imperfection thatcauses it; however, the size of the indication is the basisfor acceptance evaluation. Only indications that have anydimension greater than 1⁄16 in. (1.5 mm) shall be consid-ered relevant.

(a) A linear indication is one having a length greaterthan three times the width.

(b) A rounded indication is one of circular or ellipticalshape with a length equal to or less than three times itswidth.

(c) Any questionable or doubtful indications shall bereexamined to determine whether or not they are relevant.

A-270.4 Acceptance Standards. All surfaces to beexamined shall be free of

203

(a) relevant linear indications(b) relevant rounded indications greater than 3⁄16 in.

(5 mm)(c) four or more relevant rounded indications in a line

separated by 1⁄16 in. (1.5 mm) or less, edge to edge

QUALITY CONTROL SYSTEMA-301 GENERAL

A-301.1 Quality Control System. The Manufactureror assembler shall have and maintain a quality controlsystem which will establish that all Code requirements,including material, design, fabrication, examination (bythe Manufacturer) and inspection of boilers and boilerparts (by the Authorized Inspector), will be met. Thequality control systems of electric boiler Manufacturers,pressure relief valve manufacturers or assemblers shallinclude duties of a Certified Individual when requiredby this Section. The Certified Individual authorized toprovide oversight may also serve as the Certificate Hold-er’s authorized representative responsible for signing datareports or certificates of conformance.

Provided that Code requirements are suitably identi-fied, the system may include provisions for satisfying anyrequirements by the Manufacturer or user which exceedminimum Code requirements and may include provisionsfor quality control of non-Code work. In such systems,the Manufacturer may make changes in parts of the sys-tem which do not affect the Code requirements withoutsecuring acceptance by the Authorized Inspector. Beforeimplementation, revisions to quality control systems ofManufacturers and Assemblers of pressure relief valvesshall have been found acceptable to an ASME designeeif such revisions affect Code requirements.

The system that the Manufacturer or assembler usesto meet the requirements of this Section must be onesuitable for his own circumstances. The necessary scopeand detail of the system shall depend on the complexityof the work performed and on the size and complexityof the Manufacturer’s (or assembler’s) organization. Awritten description of the system the Manufacturer orassembler will use to produce a Code item shall be avail-able for review. Depending upon the circumstances, thedescription may be brief or voluminous.

The written description may contain information ofproprietary nature relating to the Manufacturer’s (orassembler’s) processes. Therefore, the Code does notrequire any distribution of this information, except forthe Authorized Inspector or ASME designee.

It is intended that information learned about the systemin connection with evaluation will be treated as confiden-tial and that all loaned descriptions will be returned tothe Manufacturer upon completion of the evaluation.

(10)



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2010 SECTION I

FIG. A-250.3.6-2 CHARTS FOR t OVER 1⁄4 in. (6 mm) TO 3⁄8 in. (10 mm), INCLUSIVE




1 in. (25 mm) 1 in. (25 mm)

FIG. A-250.3.6-3 CHARTS FOR t OVER 3⁄8 in. (10 mm) TO 3⁄4 in. (19 mm), INCLUSIVE




1 in. (25 mm) 1 in. (25 mm)

204



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2010 SECTION I

FIG. A-250.3.6-4 CHARTS FOR t OVER 3⁄4 in. (19 mm) TO 2 in. (50 mm), INCLUSIVE

GENERAL NOTE: Typical concentration and size permitted in any 6 in. (150 mm) length of weld.



1 in. (25 mm) 1 in. (25 mm)

FIG. A-250.3.6-5 CHARTS FOR t OVER 2 in. (50 mm) TO 4 in. (100 mm), INCLUSIVE


1 in. (25 mm) 1 in. (25 mm)



205



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2010 SECTION I

FIG. A-250.3.6-6 CHARTS FOR t OVER 4 in. (100 mm)


1 in. (25 mm) 1 in. (25 mm)



A-302 OUTLINE OF FEATURES TO BEINCLUDED IN THE WRITTENDESCRIPTION OF THE QUALITYCONTROL SYSTEM

The following is a guide to some of the features thatshould be covered in the written description of the qualitycontrol system and that is equally applicable to both shopand field work.

A-302.1 Authority and Responsibility. The authorityand responsibility of those in charge of the quality controlsystem shall be clearly established. Persons performingquality control functions shall have sufficient and well-defined responsibility, the authority, and the organiza-tional freedom to identify quality control problems andto initiate, recommend, and provide solutions.

A-302.2 Organization. An organization chart show-ing the relationship between management and engi-neering, purchasing, manufacturing, field assembling,

206

inspection, and quality control, is required to reflect theactual organization. The purpose of this chart is to identifyand associate the various organizational groups with theparticular function for which they are responsible. TheCode does not intend to encroach on the Manufacturer’sright to establish, and from time to time to alter, whateverform of organization the Manufacturer considers appro-priate for its Code work.

A-302.3 Drawings, Design Calculations, and Speci-fication Control. The Manufacturer’s or assembler’squality control system shall provide procedures whichwill assure that the latest applicable drawings, designcalculations, specifications and instructions, required bythe Code, as well as authorized changes, are used formanufacture, assembly, examination, inspection, andtesting.

A-302.4 Material Control. The Manufacturer orassembler shall include a system of receiving control

(10)



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2010 SECTION I

that will ensure that the material received is properlyidentified, has the correct documentation, includingrequired material certifications or material test reports,and satisfies Code requirements as ordered. The materialcontrol system shall ensure that only the intended materialis used in Code construction.

A-302.5 Examination and Inspection Program. TheManufacturer’s quality control system shall describe thefabrication operations, including examinations, suffi-ciently to permit the Authorized Inspector to determineat what stages specific inspections are to be performed.

A-302.6 Correction of Nonconformities. There shallbe a system agreed upon with the Authorized Inspectorfor correction of nonconformities. A nonconformity isany condition that does not comply with the applicablerules of this Section. Nonconformities must be correctedor eliminated in some way before the completed compo-nent can be considered to comply with this Section.

A-302.7 Welding. The quality control system shallinclude provisions for indicating that welding conformsto requirements of Section IX as supplemented by thisSection. Manufacturers intending to use AWS StandardWelding Procedures shall describe control measures usedto assure that the welding meets the requirements of thisSection (see PW-1.2) and Section IX.

A-302.8 Nondestructive Examination. The qualitycontrol system shall include provisions for identifyingnondestructive examination procedures the Manufacturerwill apply to conform with requirements of this Section.

A-302.9 Heat Treatment. The quality control systemshall provide controls to assure that heat treatments asrequired by the rules of this Section are applied. Meansshall be indicated by which the Authorized Inspector cansatisfy himself that these Code heat treatment require-ments are met. This may be by review of furnace time–temperature records or by other methods as appropriate.

A-302.10 Calibration of Measurement and TestEquipment. The Manufacturer or assembler shall havea system for the calibration of examination, measuring,and test equipment used in fulfillment of requirementsof this Section.

A-302.11 Records Retention. The Manufacturer orassembler shall have a system for the maintenance ofradiographs and Manufacturers’ Data Reports as requiredby this Section.

A-302.12 Sample Forms. The forms used in the qual-ity control system and any detailed procedures for theiruse shall be available for review. The written descriptionshall make necessary references to these forms.

207

A-302.13 Inspection of Boilers and Boiler Parts

A-302.13.1 Inspection of boilers and boiler partsshall be by the Authorized Inspector described in PG-91.

A-302.13.2 The written description of the qualitycontrol system shall include reference to the AuthorizedInspector and when required, the Certified Individual.

A-302.13.2.1 The Manufacturer (or assembler)shall make available to the Authorized Inspector at theManufacturer’s plant (or construction site) a current copyof the written description or the applicable quality controlsystem.

A-302.13.2.2 The Manufacturer’s quality con-trol system shall provide for the Authorized Inspector atthe Manufacturer’s plant to have access to all drawings,calculations, specifications, procedures, process sheets,repair procedures, records, test results, and any otherdocuments as necessary for the Inspector to perform hisduties in accordance with this Section. The Manufacturermay provide such access either to his own files of suchdocuments or by providing copies to the Inspector.

A-302.14 Inspection of Pressure Relief Valves

A-302.14.1 Inspection of pressure relief valvesshall be by designated representative of the ASME, asdescribed in PG-73.3.

A-302.14.2 The written description of the qualitycontrol system shall include reference to the CI and theASME designee.

A-302.14.2.1 The valve Manufacturer (or assem-bler) shall make available to the ASME designee at theManufacturer’s plant a current copy of the writtendescription of the applicable quality control system.

A-302.14.2.2 The valve Manufacturer’s (orassembler’s) quality control system shall provide for theASME designee to have access to all drawings, calcula-tions, specifications, procedures, process sheets, repairprocedures, records, test results, and any other documentsas necessary for the designee to perform his duties inaccordance with this Section. The Manufacturer may pro-vide such access either to his own files of such documentsor by providing copies to the designee.

A-302.15 Certifications. Methods other than writtensignature may be used for indicating certifications, autho-rizations, and approvals where allowed and as describedelsewhere in this Section. Where other methods areemployed, controls and safeguards shall be provided anddescribed to ensure the integrity of the certification,authorization, and approval.



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2010 SECTION I

ACCEPTANCE OF TESTINGLABORATORIES AND AUTHORIZED

OBSERVERS FOR CAPACITYCERTIFICATION OF PRESSURE

RELIEF VALVESA-311 SCOPE

These rules cover the requirements for ASME accept-ance of testing laboratories and Authorized Observers forconducting capacity certification tests of pressure reliefvalves.

A-312 TEST FACILITIES ANDSUPERVISION

The tests shall be conducted at a place where the testingfacilities, methods, procedures, and person supervisingthe tests (Authorized Observer) meet the applicablerequirements of ASME PTC 25, Pressure Relief Devices.The tests shall be made under the supervision of andcertified by the Authorized Observer. The testing facili-ties, methods, procedures, and the qualifications of theAuthorized Observer shall be subject to the acceptanceof the ASME Boiler and Pressure Vessel Committee onrecommendation of an ASME designee. Acceptance ofthe testing facility is subject to review within each 5 yearperiod. The testing laboratory shall have available forreference a copy of ASME PTC 25 and Section I.

A-313 ACCEPTANCE OF TESTINGFACILITY

Before recommendation is made to the ASME Boilerand Pressure Vessel Committee on the acceptability ofa testing facility, an ASME designee shall review theapplicant’s quality control system and testing facility, andshall witness test runs. Before a favorable recommenda-tion can be made to the Committee, the testing facilitymust meet all applicable requirements of ASME PTC 25.Uncertainty in final flow measurement results shall notexceed ±2%. To determine the uncertainty in final flowmeasurements, the results of flow tests on an object testedat the applicant’s testing laboratory will be compared toflow test results on the same object tested at the NationalBoard Testing Laboratory.

A-314 QUALITY CONTROL SYSTEM OFTESTING LABORATORY

The applicant shall prepare a Quality Control Manualdescribing his quality control system which shall clearlyestablish the authority and responsibility of those incharge of the quality control system. The manual shallinclude a description of the testing facility, testingarrangements, pressure, size and capacity limitations, and

208

the testing medium used. An organization chart showingthe relationship among the laboratory personnel isrequired to reflect the actual organization.

The Quality Control Manual shall include, as a mini-mum, the applicable requirements of this Section andASME PTC 25, including but not limited to, a descriptionof the Quality Control Manual and document control,the procedure to be followed when conducting tests, themethods by which test results are to be calculated, howtest instruments and gages are to be calibrated, and meth-ods of identifying and resolving nonconformities. Sampleforms shall be included. If testing procedure specifica-tions or other similar documents are referenced, the Qual-ity Control Manual shall describe the methods of theirapproval and control.

A-315 TESTING PROCEDURES

(a) Flow tests shall be conducted at the applicant’sfacility, including the testing of one or more valves andother flow devices (nozzle orifice or other object with afixed flow path) in accordance with the methods specifiedby this Section and ASME PTC 25. The capacity of thedevices to be tested shall fall within the testing capabilityof the laboratory being evaluated and the National BoardTesting Laboratory. The ASME designee will observethe procedures and methods of tests, and the recordingof results.

(b) The devices tested at the applicant’s facility willthen be tested at the National Board Testing Laboratoryin Columbus, Ohio, to confirm the test results obtained.Agreement between the results of the two laboratoriesshall be within ±2%. The purpose of comparing testresults at the two laboratories is not only to check proce-dures but also all test instruments and equipment of theapplicant’s facility over the capacity and pressure rangeproposed. Since the capabilities of each laboratory aredifferent, no specific number of tests can be predeter-mined. The number will be in accordance with the flowcapability and measurement techniques available at thelaboratory being evaluated. Provided the above tests andcomparisons are found acceptable, the ASME designeewill submit a report to the Society recommending thelaboratory be accepted for the purpose of conductingcapacity certification tests. If a favorable recommendationcannot be given, the ASME designee will provide, inwriting to the Society, the reasons for such a decision.

A-316 AUTHORIZED OBSERVERS

An ASME designee shall review and evaluate the expe-rience and qualifications of persons who wish to be desig-nated as Authorized Observers. Following such reviewand evaluation the ASME designee shall make a reportto the Society. If a favorable recommendation is not made,



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2010 SECTION I

full details shall be provided in the report.Persons designated as Authorized Observers by the

ASME Boiler and Pressure Vessel Committee shall super-vise capacity certification tests only at testing facilitiesspecified by the Committee.

A-317 CYLINDRICAL COMPONENTSUNDER INTERNAL PRESSURE

A-317.1 General. The requirements of this Appendixmay be used in place of the requirements of PG-27 todetermine the minimum required thickness or the maxi-mum allowable working pressure of piping, tubes, drums,shells, and headers for temperatures not exceeding thosegiven for the various materials listed in Tables 1A and1B of Section II, Part D. The calculated and orderedthickness of material must include the requirements ofPG-16.2, PG-16.3, and PG-16.4. Design calculationsmust include the loadings as defined in PG-22. Whenrequired by the provisions of this Code, allowance mustbe provided in material thickness for threading and mini-mum structural stability (see PWT-9.2 and A-317.3,Notes 3 and 5).

A-317.2 Formula for CalculationA-317.2.1 Formulas (Based on the Strength of

the Weakest Course). The minimum required thicknessshall be calculated from

t p D (1 − e(−P/SE))/2 + C + f

or

t p Di (e(P/SE) − 1)/2 + C + f

For the maximum allowable pressure, this becomes

P p SE loge{D/[D − 2(t − C − f)]}

or

P p SE loge {[Di + 2(t − C − f)]/Di}

where

C p minimum allowance for threading and structuralstability (see A-317.3, Note 3)

D p outside diameter of cylinder, less any portion ofC that might pertain to the O.D.

Di p inside diameter of cylinder, plus any portion ofC that might pertain to the I.D.

E p efficiency (see A-317.3, Note 1)e p the base of natural logarithmsf p thickness factor for expanded tube ends (see

A-317.3, Note 4)P p maximum allowable working pressure (see

PG-21)S p maximum allowable stress value at the design

temperature of the metal, as listed in the tables

209

specified in PG-23 (see A-317.3, Note 2)t p minimum required thickness (see A-317.3,

Note 6)w p weld joint strength reduction factor per PG-26

A-317.2.1.2 The wall thickness of the ends oftubes strength-welded to headers or drums need not bemade greater than the run of the tube as determined bythis equation.

A-317.2.1.3 A tube in which a fusible plug is tobe installed shall be not less than 0.22 in. (5.6 mm) inthickness at the plug in order to secure four full threadsfor the plug (see also A-20).

A-317.2.1.4 Bimetallic sections meeting therequirements of PG-9.4 shall use as an outside diameterD, in the equation given in A-317.2.1, not less than thecalculated outside diameter of the core material. Theoutside diameter of the core material shall be determinedby subtracting the minimum thickness of the claddingfrom the outside diameter of the bimetallic section,including the maximum plus tolerance. The minimumrequired thickness t should apply only to the core material.

A-317.3 Notes. Notes applicable to the equation givenin A-317.2.1 are as follows:

(a) Note 1


p ligament efficiency per PG-52 or PG-53 forseamless cylinders with ligaments

p w, the weld joint strength reduction factor perPG-26 for longitudinally welded cylinders with-out ligaments

For longitudinally welded cylinders with liga-ments located such that no part of the longitudi-nal weld seam is penetrated by the openingsforming the ligament, E shall be taken as thelesser of w or the ligament efficiency from PG-52 or PG-53. If any part of the longitudinal seamweld is penetrated by the openings that form theligaments, E shall be taken as the product of wtimes the ligament efficiency.

(b) Note 2. The temperature of the metal to be usedin selecting the S value shall be not less than the maximumexpected mean wall temperature, i.e., the sum of theoutside and inside surface temperatures divided by 2. Forsituations where there is no heat absorption, the metaltemperature may be taken as the temperature of the fluidbeing transported, but not less than the saturation temper-ature.

(c) Note 3. Any additive thickness represented by thegeneral term C may be considered to be applied on theoutside, the inside, or both. It is the responsibility of thedesigner using these equations to make the appropriateselection of diameter or radius to correspond to the



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2010 SECTION I

intended location and magnitude of this added thickness.The pressure- or stress-related terms in the equationshould be evaluated using the diameter (or radius) and theremaining thickness which would exist if the “additive”thickness had not been applied or is imagined to havebeen entirely removed.

The values of C below are mandatory allowances forthreading. They do not include any allowance for corro-sion and/or erosion, and additional thickness should beprovided where they are expected.

Threaded Sections, in. (mm) Value of C, in. (mm)

3⁄4 (19) nominal, and smaller 0.065 (1.65)1 (25) nominal, and larger depth of thread h

(1) Steel or nonferrous pipe lighter than Schedule40 of ASME B36.10M, Welded and Seamless WroughtSteel Pipe, shall not be threaded.

(2) The values of C stiplulated above are such thatthe actual stress due to internal pressure in the wall ofthe pipe is not greater than the values of S, given inTable 1A of Section II, Part D, as applicable in the equa-tions.

(3) The depth of thread h in inches may be deter-mined from the equation h p 0.8/n, where n is the numberof threads per inch.

(d) Note 4

f p 0.04 in. (1.0 mm) over a length at least equalto the length of the seat plus 1 in. (25 mm) fortubes expanded into tube seats, except

p 0 for tubes expanded into tube seats, providedthe thickness of the tube ends over a length ofthe seat plus 1 in. (25 mm) is not less than thefollowing:

p 0.095 in. (2.41 mm) for tubes 11⁄4 in. (32 mm)O.D. and smaller

p 0.105 in. (2.67 mm) for tubes above 11⁄4 in.(32 mm) O.D. and up to 2 in. (50 mm) O.D.

p 0.120 in. (3.05 mm) for tubes above 2 in.(50 mm) O.D. and up to 3 in. (75 mm) O.D.



p 0 for butt welds and for tubes strength-weldedto headers and drums

210

(e) Note 5. While the thickness given by the equationis theoretically ample to take care of both bursting pres-sure and material removed in threading, when steel pipeis threaded and used for steam pressures of 250 psi(1 720 kPa) and over, it shall be seamless and of a weightat least equal to Schedule 80 in order to furnish addedmechanical strength.

(f) Note 6. If pipe is ordered by its nominal wall thick-ness, as is customary in trade practice, the manufacturingtolerance on wall thickness shall be taken into account.After the minimum pipe wall thickness t is determinedby the equation, this minimum thickness shall beincreased by an amount sufficient to provide the manufac-turing tolerance allowed in the applicable pipe specifica-tion. The next heavier commercial wall thickness maythen be selected from Standard thickness schedules ascontained in ASME B36.10M. The manufacturing toler-ances are given in the several pipe specifications listedin PG-9.

(g) Note 7. When computing the allowable pressurefor a section of a definite minimum wall thickness, thevalue obtained by the equations may be rounded out tothe next higher unit of 10.

DATA REPORT FORMS AND GUIDES

A-350 GUIDES FOR COMPLETINGMANUFACTURERS’ DATA REPORTFORMS

Immediately following each of the included DataReport Forms (P-2, P-2A, P-2B, P-3, P-3A, P-4, P-4A,P-4B, P-5, P-7, and P-8) is a guide for completing thatform. The explanations included in the guides are keyedto the Data Report Forms in the following manner:

① Circled numbers on each of the forms refer to theitems listed on the applicable guide.

1 Numbers without circles appearing in the guide iden-tify specific line or item numbers of the form.

No guide is provided for completing Form P-6, Manu-facturer’s Data Report Supplementary Sheet.

A-357 of Appendix A is a guide for determining theData Report Forms required for Section I construction.

Any quantity to which units apply shall be entered onthe Manufacturer’s Data Report with the chosen units.



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(10)

F11

F4 F5 F5 F5 F5 F6

F7

F8

F9

F10 F11

F12 F13 F14

F11

F11

F15 F16 F16

F17

F11 F12

F18 F11 F19

F20

F11 F21 F23 F23 F23

F24

F25

F1

F2

F3

FORM P-2 MANUFACTURER’S DATA REPORT FOR ALL TYPES OF BOILERS

EXCEPT WATERTUBE AND ELECTRIC

As Required by the Provisions of the ASME Code Rules, Section I

1. Manufactured by(Name and address of manufacturer)

2. Manufactured for(Name and address of purchaser)

3. Location of Installation(Name and address)

4. Type Boiler No. Year Built(HRT, etc.) (Mfr’s. Serial No.) (CRN) (Drawing No.) (Nat’l Board No.)

5. The chemical and physical properties of all parts meet the requirements of material specifications of the ASME BOILER AND PRESSURE VESSEL

CODE. The design, construction, and workmanship conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE ,(Year)

Addenda to (if applicable), and Code Cases(Date) (Numbers)

Manufacturer’s Partial Data Reports properly identified and signed by Commissioned Inspectors are attached for the following items of this report:

(Name of part, item number, mfr’s. name and identifying stamp)

6. Shells or drums(no.) (mat’l. spec. gr.) (thickness) [diameter (ID)] (length, inside) (length, inside)

7. Joints[long (seamless, welded)] [efficiency (as compared with seamless)] [girth (seamless, welded)] (no. of shell courses)

8. Heads(Material Specification No.: Thickness — Flat, Dished, Ellipsoidal — Radius of Dish)

9. Tubesheet Tube Holes(Mat’l. Spec., Grade, Thickness) (Diameter)

10. Boiler Tubes: No.(Mat’l. Spec., Grade) (Straight or Bent)

Diameter Length Gage(If various, give max. & min.) (or thickness)

11. Furnace No. Size Length, each section Total(O.D. or WxH)

Type(Plain, Adamson, Ring Reinforced, Corrugated, Combined, or Stayed)

Seams: Type(Mat’l. Spec., Grade, Thickness) (Seamless, Welded)

12. Staybolts: No. Size(Diameter, Mat’l. Spec., Grade, Size Telltale, Net Area)

Pitch MAWP psi.(Horizontal and Vertical)

13. Stays or braces

MaterialSpec. No.

No.and Size

Fig. PFT-32L/I

Dist. Tubesto Shell MAWPLocation Type

MaximumPitch

(a) F.H. above tubes

(b) R.H. above tubes

(c) F.H. below tubes

(d) R.H. below tubes

(e) Through stays

(f) Dome braces

14. Other Parts. 1. 2. 3.(Brief Description — i.e., Dome, Boiler Piping, etc.)

1.

2.

3.(Mat’l. Spec., Grade, Size, Material Thickness, MAWP)

[diameter (ID)]

(07/10)

211



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F26

F27 F28 F29

F31

F32

F23

F34

F35

F36

F37

F38

F39 F39 F39

F40

F34

F37

F30

F39

F41

F5 F5 F5 F5

FORM P-2

15. Openings: (a) Steam (b) Pressure Relief Valve(No., Size, and Type) (No., Size, and Type)

(c) Blowoff (d) Feed(No., Size, Type, and Location) (No., Size, Type, and Location)

(e) Manholes: No. Size Location

(f) Handholes: No. Size Location

16. Fusible Plug (if used)(No., Diameter, Location, and Mfr’s. Stamp)

17. Boiler Supports: No. Type Attachment(Saddles, Legs, or Lugs) (Bolted or Welded)

18. MAWP Based On Heating Surface(Code Para. and/or Formula) (Total)

19. Shop Hydrostatic Test 20. Maximum Designed Steaming Capacity

21. Remarks

CERTIFICATE OF SHOP COMPLIANCE

Our Certificate of Authorization no. to use the (S) symbol expires

Date Signed Name(Authorized Representative) (Manufacturer)

Boiler constructed by at .

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the state or province

of and employed byhave inspected parts of this boiler referred to as data items

and have examined Manufacturer’s Partial Data Reports for items

and state that, to the best of my knowledge and belief, the manufacturer has

constructed this boiler in accordance with Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

Date Signed Commissions(Authorized Inspector) [Nat’l. Board (incl. endorsements), State, Province, and No.]

CERTIFICATE OF FIELD ASSEMBLY COMPLIANCE

Our Certificate of Authorization no. to use the (A) or (S) symbol expires

Date Signed Name(Authorized Representative) (Assembler)

CERTIFICATE OF FIELD ASSEMBLY INSPECTION

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the state or province

of and employed by


CERTIFICATE OF SHOP INSPECTION

(04/09)

We certify that the statements made in this data report are correct and that all details of design, material, construction, and workmanship of this boiler conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the boiler described in this Manufacturer’s Data Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspection.

We certify that the field assembly construction of all parts of this boiler conforms with the requirements of Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

have compared statements in this Manufacturer’s Data Report with the described boiler and state that the parts referred to as data items

-------- ---------------, not included in the certificate of shop inspection, have been inspected by me and that, to the best of my knowledge and

belief, the manufacturer and/or the assembler has constructed and assembled this boiler in accordance with the applicable sections of the ASME

BOILER AND PRESSURE VESSEL CODE. The described boiler was inspected and subjected to a hydrostatic test of

By signing this certificate, neither the inspector nor his employer makes any warranty, expressed or implied, concerning the boiler described in

this Manufacturer’s Data Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or

property damage or a loss of any kind arising from or connected with this inspection.

.

Boiler No.(Mfr’s. Serial No.) (CRN) (Drawing No.) (Nat’l Board No.)

212



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(10)A-351 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT, FORM P-2 (See PG-112.2.1)

F1 Name and address of Manufacturer, i.e., maker of all components not covered by Partial Data Reports.

F2 Name and address of purchaser and/or owner.

F3

F4 Show type of boiler documented by this Data Report.

F5 Identification of boiler by applicable numbers. If intended for installation in Canada, indicate the Canadian DesignRegistration Number and drawing number. To be shown on all pages of Form P-2.

F6 Year in which fabrication was completed in shop.

F7 Date (year) of Section I Edition under which boiler was constructed.

F8 Issue date of most recent Addenda (if applicable) to Section I under which boiler was constructed (e.g., “1990”).

F9 To be completed when one or more components comprising the boiler are furnished by others and certified by PartialData Report(s), Form P-4.

F10

F11 Show the complete ASME Material Specification No. and Grade as listed in the appropriate stress allowance table inthe Appendix of Section I (e.g., “SA-285-B”). Exception: A specification number for a material not identical to an ASMESpecification may be shown only if such material meets the criteria in the Foreword of this Section. When material isaccepted through a Code Case, the applicable Case number shall be shown.

F12 Indicate type of joint(s).

F13 Show joint efficiency for welded joints.

F14 Same as F12 above.

F15 Show number of furnaces in boiler.

F16 For cylindrical furnaces of the Adamson, ring reinforced, and combined types, show length of each section and totallength. For other types, show total length only.

F17 For stayed (firebox) type furnace, also complete Line 12.

F18 If threaded, show diameter at root of thread.

F19 Minimum cross-sectional area after deducting for telltale hole.

F20 Maximum allowable working pressure for the stayed area calculated according to the rules contained in Part PFT.

F21 Type of stay or brace, e.g., diagonal, girder, through, etc.

F22 Deleted.

F23 See applicable paragraphs and figures in Part PFT.

F24 List parts not covered elsewhere on the Data Report. If insufficient space, attach a supplementary sheet (Form P-6).

F25 Tabulate data for parts listed on Line 14.

F26 Show data for main, auxiliary steam outlets, and feedline connections only. Does not apply to small openings for watercolumns, controls, vents, drains, instrumentation, or to openings for connections internal to the boiler such as risers,downtakes, or downcomers.

F27 Maximum allowable working pressure established in accordance with PG-21.

F28 Show Section I paragraph that applies to the weakest part of the boiler as established by calculation or deformation test.

F29 Boiler heating surface calculated in accordance with PG-101.

F30 Hydrostatic pressure applied in accordance with PG-99 and witnessed by the Authorized Inspector.

F31 To be completed and signed by an authorized representative of the Manufacturer.

F32 Show Manufacturer’s ASME Certificate of Authorization number, kind of symbol, and date of expiration of said authori-zation.

F33 This certificate to be completed by the Authorized Inspection Agency representative who performs the in-shop inspection.

Show quantity and inside dimensions. If more than two shells or drums are used, enter data in Line 14.

Name and address of location where boiler is to be installed. If not known, so indicate (e.g., “Not known — built for stock”).

Any quantity to which units apply shall be entered on the Manufacturer’s Data Report with the

chosen units.

213



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2010 SECTION I

F34 To determine what goes in the space, you should be guided by the following:National Board Stamped Boilers and Pressure Vessels (see Form P-2 Line 4)After “and/or State or Province” in the certification blocks—

If the Inspector has a valid commission for the state or province where the Manufacturer’s shop is located, insertthe name of that state or province. If the Manufacturer is located in a non-Code state or province, insert the name ofthe state or province where the Inspector took his original examination to obtain his National Board Commission,provided he still has a valid commission for that state or province. Otherwise, if no valid commission, show the nameof the state or province where he has a valid commission authorizing him to make the shop inspection.

Boilers and Pressure Vessels Not Stamped National BoardFollow the above procedure. However, in this case do not list any National Board Commission number after theInspector’s signature at the bottom of the block.

F35 Indicate in this space the data items covered on Form P-2 on Lines 6 through 20.

F36 Indicate by Line numbers those items furnished by other and for which Partial Data Reports (Form P-4) have beenexamined.

F37 The Inspector’s National Board commission number must be shown when the boiler is stamped National Board; otherwiseshow only his state or province commission number. (See F34 above.)

F38 To be completed when applicable, and signed by an authorized representative of the organization responsible for fieldassembly of the boiler.

F39 Show assembler’s ASME Certificate of Authorization number, kind of symbol, and date of expiration of said authorization.

F40 This certificate to be completed by the Authorized Inspection Agency representative who performs the field assemblyinspection.

F41 Show page number and total number of pages of Form P-2.

214



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2010 SECTION I

(10)

F

F

F

1

2

3

F5 F5F4

F5 F5 F6

F9

F7

F11F10

F8

F12 F13 F14

F18

F19 F20

F15

F16 F17

F22

F24 F24

F24

F23

FORM P-2A MANUFACTURER’S DATA REPORT FOR ALL TYPES OF ELECTRIC BOILERS


CERTIFICATE OF COMPLIANCE OF BOILER PRESSURE VESSEL

1. Manufactured by

PART I —— To Be Completed by the Manufacturer of the Bolier Pressure Vessel

(Name and address of manufacturer of boiler pressure vessel)

(Name and address of purchaser)

(Name and address)

(resistance element, electrode)

(Drawing No.) (Nat’l. Brd. No.)

(Name of part, item number, mfr’s. name, and identifying stamp)

(Year)

(Mfr’s. Serial No.) (CRN)

2. Manufactured for

3. Location of Installation

(thickness) (length, inside) (length, inside)[diameter (ID)] [diameter (ID)]6. Shells or drums

Manufacturer’s Partial Data Reports properly identified and signed by Commissioned inspectors are attached for the following items of this report:

4. Type

5. The chemical and physical properties of all parts meet the requirements of Material Specifications of the ASME BOILER AND PRESSURE VESSEL

CODE. The design, construction, and workmanship conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE

Addenda to (if applicable), and Code Cases

Boiler No.

Year Built

,

(Numbers)(Date)

(no.)

7. Joints[long (seamless, welded)]

10. Openings: (a) Steam(No., size, and type)

(Code para. and/or formula)

(Authorized Representative) (Mfr. of boiler pressure vessel)

(c) Blowoff

(e) Manholes: No. Size Location

(f) Handholes: No. Size

(g) Elements/Electrodes: No. Size Location

Location

(b) Pressure Relief Valve

(d) Feed(No., size, and type)

Attachment(bolted or welded)

(No., size, and type)

(No., size, type, and location)

8. Heads

9. Other Parts. 1.

1.

2.

3.

2. 3.Brief description — i.e., dome, boiler piping, etc.)

[efficiency (as compared with seamless)]

(Mat’l. Spec. No.: thickness — flat, dished, ellipsoidal — radius of dish)

11. Boiler Supports: No.

12. MAWP

13. Shop Hydrostatic Test

We certify the statements in Part I of this Data Report to be correct.

Our Certificate of Authorization No. to use the (S) or (M)

Symbol expires

Date Signed Name

14. Maximum Designed Steaming Capacity

15. Remarks

Based on

Type(saddles, legs, or lugs)

(Mat’l. Spec., Gr., size, material thickness, MAWP)

[girth (seamless, welded)] (no. of shell courses)

(mat’l. spec. gr.)

.

(07/10)

215



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2010 SECTION I

F32

F25

F26

F29

F30

F22

F35

F24F24

F24

F31

F28

F27

F26

F34

F29

F33

F5 F5 F5 F5

FORM P-2A

Boiler pressure vessel made by

Date

of

and have examined Manufacturer’s Partial Data Reports for itemshave inspected parts of this boiler pressure vessel referred to as data items

and employed by

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the State or Province

Part II—To Be Completed by the Manufacturer Responsible for the Completed Boiler

16.

17. Pressure Relief Valve(s) No. Size Set Press Total Capacity

(a) Steam Pipe

(b) Feed Water

(c) Blowoff

Feed Water

Stop

Check

18. Heating Elements Installed: Quantity Total Power Input

19. Electrodes: Quantity Total Power Input

20. Hydrostatic Test of Completed Boiler MAWP of completed boiler

21. Serial No. Assigned by Manufacturer Responsible for Completed Boiler

Commissions

at

Bolted, Threaded,or WeldedItem Size Size Type Rating No.Sch. Spec.

Piping Valves

CERTIFICATE OF COMPLIANCE OF COMPLETED BOILER

CERTIFICATE OF SHOP INSPECTION OF COMPLETED BOILER

CERTIFICATE OF SHOP INSPECTION OF BOILER PRESSURE VESSEL

Date

Commissions

and state that, to the best of my knowledge and belief, the Manufacturer has constructed this boiler in accordance with the applicable sections of the

ASME BOILER AND PRESSURE VESSEL CODE.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the boiler described in this

Manufacturer’s Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property

damage or a loss of any kind arising from or connected with this inspection.

and state that, to the best of my knowledge and belief, the manufacturer has constructed this boiler pressure vessel in accordance with the applicable

sections of the ASME BOILER AND PRESSURE VESSEL CODE.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the boiler pressure vessel

described in this Manufacturer's Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal

injury or property damage or a loss of any kind arising from or connected with this inspection.

(04/09)

We certify that this completed boiler conforms with the requirements of Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

Our Certificate of Authorization No. to use the (S), (M), or (E)

Symbol expires

Date Signed By

Boiler made by

of

boiler and have examined Manufacturer’s Partial Data Reports forand have inspected the completed

and employed by

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the State or Provinceat

of

(Authorized Inspector)

(Check one) ( Authorized Representative

( Certified Individual

(Assembler)

[Nat’l. Board (incl. endorsements), State, Province, and No.]

(Authorized Inspector) [Nat’l. Board (incl. endorsements), State, Province, and No.]


216



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2010 SECTION I

(10)

F38

F37

F32

F24 F24 F24

F26

F34

F29

FORM P-2A

CERTIFICATE OF FIELD ASSEMBLY INSPECTION BY AN AUTHORIZED INSPECTOR OF THE COMPLETED BOILER

CERTIFICATE OF FIELD ASSEMBLY INSPECTION BY ASSEMBLER OF THE COMPLETED BOILER

CERTIFICATE OF FIELD ASSEMBLY COMPLIANCE OF THE COMPLETED BOILER

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the state or provinceBOILER FIELD ASSEMBLED BY

and employed byhave inspected the completed field assembled electric

boiler, have examined the Manufacturer’s Partial Data Reports forand state that, to the best of my knowledge and belief, the Assembler has constructed, assembled, and tested this boiler in accordance with theapplicable section(s) of the ASME BOILER AND PRESSURE VESSEL CODE.By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the boiler described in this Manufacturer’s Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspection.

Date Signed Commissions

at

I, the undersigned, as an authorized Certified Individual representing and employed byhave examined this Manufacturer’s Data Report (including any Manufacturer’s partial data reports) and have compared the documentation with thedescribed field assembled electric boiler. The completed field assembled boiler was inspected by me and subjected to a hydrostatic test of psi. To the best of my knowledge and belief I state that the electric boiler identified in this report has been constructed, assembled, inspected, and tested by the Assembler in accordance with the applicable section(s) of the ASME BOILER AND PRESSURE

VESSEL CODE.

BOILER FIELD ASSEMBLED BY at

(Authorized Inspector) (Nat’l. Board including Endorsements, State, Province, and No.)

(07/10)

ofof

Our Certificate of Authorization No.

Date Signed Name

Symbol expires .to use the (S) or (E)

Check one �Authorized Representative �Certified Individual

Date Signed Assembler(Certified Individual)

(Assembler)

We certify that the field assembly of the completed electric boiler identified on this form conforms to the requirements of Section I of the ASME

BOILER AND PRESSURE VESSEL CODE.

217



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2010 SECTION I

(10) A-351.1 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT, FORM P-2A (See PG-112.2.1.1)

F1 Name and address of Manufacturer, i.e., maker of all components not covered by Partial Data Reports. When the boilerpressure vessel is constructed by a “U” symbol holder and certified on a U-1 or U-1A Data Report, indicate on line 1“Boiler pressure vessel constructed to Section VIII, Division 1, as permitted by Part PEB,” and attach the U-1 or U-1AData Report.

F2 Name and address of purchaser and/or owner (to be completed by the Manufacturer of the completed boiler).

F3 Name and address of location where boiler is to be installed. If not known, so indicate (e.g., “Not known—built forstock”) (to be completed by the Manufacturer of the completed boiler).

F4 Show type of electric boiler documented by this Data Report.

F5 Identification of boiler by applicable numbers. If intended for installation in Canada, indicate the Canadian DesignRegistration Number and drawing number. To be shown on all pages of Form P-2A.

F5a The Manufacturer of the boiler pressure vessel shall apply the ASME Code symbol stamp and the National BoardNumber when required. It is his responsibility to complete Part I of the Data Report, and forward it with the vessel tothe company who will apply the trim (“E” symbol holder). The Manufacturer responsible for the trim and completedboiler shall complete Part II of the Data Report and if the boiler is to be stamped “National Board,” forward the originalData Report to the National Board for registration.



F8 Issue date of most recent Addenda (if applicable) to Section I under which boiler was constructed (e.g., “1990”).

F9 To be completed when one or more components comprising the boiler pressure vessel and furnished by others andcertified by Partial Data Report(s), Form P-4.

F10 Show quantity and inside dimensions in inches. If more than two shells or drums are used, enter data in Line 9.


F12 Indicate type of joint(s).

F13 Show joint efficiency for welded joints.


F15 List parts not covered elsewhere on the data report. If insufficient space, attach a supplementary sheet (Form P-6).

F16 Tabulate data for parts listed on Line 9.


F18 Show data for main and auxiliary steam outlets only. Does not apply to small openings for water column, controls,vents, etc.

F19 Maximum allowable working pressure established in accordance with PG-21.

F20 Show Section I paragraph which applies to the weakest part of the boiler pressure vessel as established by calculationor deformation test.

F21 Deleted.






chosen units.

218



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2010 SECTION I

F26 To determine what goes in the space, you should be guided by the following:

National Board Stamped Boilers and Pressure Vessels (see Form P-2A Line 4)After “and/or State or Province” in the certification blocks—

If the Inspector has a valid commission for the state or province where the Manufacturer’s shop is located, insertthe name of the state or province. If the Manufacturer is located in a non-Code state or province, insert the name ofthe state or province where the Inspector took his original examination to obtain his National Board Commission,provided he still has a valid commission for that state or province. Otherwise, if no valid commission, show the nameof the state or province where he has a valid commission authorizing him to make the shop inspection.


F27 Indicate in this space the data items covered on Form P-2 on Lines 6 through 14.

F28 Indicate by Line numbers those items furnished by others and for which Partial Data Reports (Form P-4) have beenexamined.

F29 The Inspector’s National Board commission number must be shown when the boiler is stamped “National Board”;otherwise show only his state or province commission number. (See F26 above.)

F30 When piping is supplied with the boiler for steam, blowoff, and feedwater, complete this section. When welded pipingis supplied by another stamp holder, leave blank, and provide separate Form P-4A.

F31 Complete this section when valves are furnished with the boiler.

F32

F33 This certificate to be completed by the Authorized Inspection Agency representative who performs the in-shop inspection.Leave blank where final shop inspection is not required as permitted by PEB-18.1.

F34 Indicate in this space if the welded piping is furnished by others and is covered on Form P-4A or Form P-4B.

F35 Serial number assigned by the Manufacturer responsible for the completed boiler. This may be the same number as the serial number shown on Line 4.

To be completed and signed by an Authorized Representative or a Certified Individual (when applicable per PEB-18.5) of the organization responsible for assembly of the boiler. Show ASME Certificate of Authorization number, kind of symbol, and date of said authorization. When the boiler pressure vessel is constructed by a “U” symbol holder and certified on a U-1 or U-1A Data Report, the “E” symbol holder shall complete Lines 1 through 4 of Part 1.

F36 Show page number and total number of pages of Form P-2A.

F37 To be completed and signed by a Certified Individual employed by the Assembler responsible for the field assemblyof the boiler (when applicable per PEB-18.5).

F38 This certificate to be completed by the Authorized Inspection Agency representative who performs the finalinspection of a field assembled electric boiler. Leave blank where final inspection of a field assembled electricboiler is not required as permitted by PEB-18.1.

219



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2010 SECTION I

(10)

1

2

3

4 5

13 14 15 16

12

17

20 21

27 28 29 13 30 31

22 23 24 25

32

43

33 34 35

36

39

42

37

38

40 40 40

26

13 13

18

11

7 8 96

10


FORM P-2B MANUFACTURER’S DATA REPORT FOR ELECTRIC SUPERHEATERS AND REHEATERS



3. Location of installation(Name and address)

4. Type

5. The chemical and physical properties of all parts meet the requirements of Material Specifications of the ASME BOILER AND PRESSURE VESSEL CODE. The design, construction, and workmanship conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE

Description of vessel (reheater, superheater) (Drawing or Part No.)

6. ShellMat’l. (Spec. No., Grade) Nom. Thk. Diameter OD Length OA

(Numbers)

7. SeamsLongitudinal (Welded, Double, Single, Butt)

Location (Top,Bottom, Ends)

Purpose

Inlet (Feed)

No. Diam. or Size Type

(b)(a)

Thickness

Material Nom. Thk. Location

Type of Head(Flat, Dished, Ellipsoidal, Hemispherical) Radius of Dish

Side to PressureConvex, Concave

Circumferential Joint(s)Indicate Type

10. Supports: Skirt Lugs Legs Saddles Other Attached(Yes or No)

(Authorized Representative) (Manufacturer)

Date Signed Commissions(Authorized Inspector) [Nat’l. Board (including endorsements), State, Province, and No.]

11. Design Specifications MAWP Maximum Discharge Temperature (Heated Media) Hydro test

12. Heating elements installed: Quantity Total

13. Pressure Relief Valve(s) (if supplied) No. Size Set Pressure


41 CERTIFICATE OF SHOP INSPECTION

Total Capacity lb/hr

Our Certificate of Authorization No. to use the (S) Symbol expires

We certify that the statements made in the data report are correct and that all details of design, material, construction, and workmanship of thisboiler pressure vessel part conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

Boiler pressure vessel made byI, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the state or provinceofhave inspected the boiler pressure vessel described in this Manufacturer’s Data Report and have examined Manufacturer’s Partial Data Reports foritemsaccordance with Section I of the ASME BOILER AND PRESSURE VESSEL CODE. By signing this certificate, neither the Inspector nor his employermakes any warranty, expressed or implied, concerning the boiler pressure vessel described in this Manufacturer’s Data Report.Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kindarising from or connected with this inspection.

and state that, to the best of my knowledge and belief, the Manufacturer has constructed this boiler pressure vessel in

and employed by

at

Date Signed Name

14. Remarks

(No.) (No.) (Where and How)(No.)

If removable, bolts used (describe other fasteners)

9. Nozzle, inspection and pressure relief valve openings:(Mat’l. Spec. No., Grade, Size, No.)

8. Heads (a)(Mat’l. Spec. No., Grade or Type)

(b)(Mat’l. Spec. No., Grade or Type)

Girth (Welded, Double, Single, Butt) No. & Length of Shell Courses

19

Addenda to (if applicable), and Code Cases(Date)

(Mfr’s Serial No.) (CRN) (National Board No.) (Year built)

(Year)

Outlet (Steam)

Drain

Pressure Relief Valve(s)

Inspection Openings (if applicable)

(07/10)

220



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2010 SECTION I

44

45 45

43

46

45

42

47

35

(Authorized Representative) (Assembler)

Date Signed Commissions(Authorized Inspector)



FORM P-2B

Our Certificate of Authorization No. to use the (A) or (S) Symbol expires

We certify that the field assembly of parts referred to as data itemson this form conform to the requirements of Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

identified

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the state orprovince ofhave compared statements in this Manufacturer’s Data Report with the described boiler and state that the parts referred to as data items

and employed by

Inspection, have been inspected by me and that, to the best of my knowledge and belief, the Manufacturer and/or the assembler has constructedand assembled this boiler in accordance with the applicable section(s) of the ASME BOILER AND PRESSURE VESSEL CODE. The describedboiler was inspected and subjected to a hydrostatic test ofemployer makes any warranty, expressed or implied, concerning the boiler described in this Manufacturer’s Data Report. Furthermore, neitherthe Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from orconnected with this inspection.

. By signing this certificate, neither the Inspector nor his

, not included in the Certificate of Shop

Date Signed Name

[Nat’l. Board (including endorsements), State, Province, and No.]

(03/07)

F6 F7 F8

(Mfr’s. Serial No.) (CRN) (Nat’l Board No.)

221



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2010 SECTION I

(10) A-351.2 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT FORM P-2B

Any quantity to which units apply shall be entered on the Manufacturer’s Data Report with the chosen units.

F1 Name and address of the Manufacturer, i.e. maker of all components not covered by Supporting Data Reports.


F3 Name and address of location where boiler pressure vessel is to be installed. If not known, so indicate (e.g., “Notknown”).

F4 Description or applications of boiler pressure vessel, i.e., superheater, reheater, other (specify).

F5 Identification of boiler pressure vessel by applicable numbers. Indicate the organization that prepared the drawing ifother than the manufacturer listed in F1 .

F6 Manufacturer’s Serial Number. To be shown on all pages of Form P-2B.

F7 Indicate the Canadian Registration Number when applicable. To be shown on all pages of Form P-2B.

F8 Where applicable, the National Board number from the Manufacturer’s Series of National Board numbers. To be shownon all pages of Form P-2B.

F9 Year in which fabrication was completed in the shop.

F10 Date (year) of Section I Edition under which the boiler pressure vessel was constructed.

F11 Issue date of the Addenda (if applicable) to Section I under which the boiler pressure vessel was constructed.

F12 All Code Case numbers and revisions used for construction must be listed. Where more space is needed use “Remarks”section or list on a separate page.

F13 Show the complete ASME Material Specification No. and Grade as listed in the appropriate stress allowance table inSection II, Part D (e.g., “SA-285-B”). Exception: A specification number for a material not identical to an ASME Specificationmay be shown only if such material meets the criteria in the Foreword of this Section. When material is acceptedthrough a Code Case, the applicable Case number shall be shown.

F14 Thickness is the nominal thickness of the material used in the fabrication of the vessel shell.

F15 Outside diameter of shell.

F16 Overall length of shell.

F17 Type of longitudinal joint in shell. If seamless, indicate joint type as S, and E for electric resistance welded.

F18 Type of circumferential or girth joint in shell.

F19 Total number of courses or sections between end closures (heads) required to make one shell. Length of the shell(courses, excluding heads, in feet and inches.

F20 Location of head.

F21 Specified minimum thickness of the head after forming.

F22 Type of head — flat, dished, ellipsoidal, hemispherical, etc.

F23 Indicate the radius (inside or outside) of the head.

F24 Indicate the side of dished head to pressure.

F25 Type of circumferential joint used to attach head to shell.

F26 Bolts or other fasteners used to secure removable head or heads of vessel. Indicate the number, size, and materialspecification (grade/type).

F27 Nozzles, pressure relief valve and, when applicable, inspection openings.

F28 Indicate nozzles by size and inspection openings by inside dimensions.

F29 Describe type as flanged, welding neck, etc.

222



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2010 SECTION I

F30 Nominal thickness applies to nozzle neck thickness.

F31 “Location” applies to inspection openings only (when applicable).

F32 Describe supports, location, and method of attachment.

F33 Show maximum allowable working pressure (internal) for which vessel is constructed.

F34 Indicate maximum allowable discharge temperature of heated media.


F36 Indicate the total number of individual elements and total installed kilowatts.

F37 List pressure relief valve specifications if supplied with boiler pressure vessel.

F38 Any information to clarify the report should be entered here. When applicable and when it is known, indicate the NationalBoard Number of the completed boiler.


F40 Show Manufacturer’s ASME Certificate of Authorization number, kind of symbol, and date of expiration of saidauthorization.



National Board Stamped Boilers and Pressure Vessels (See Form P-2B Line 4)After ”and/or State or Province” in the certification blocks —

If the Inspector has a valid commission for the state or province where the Manufacturer’s shop is located, insert thename of that state or province. If the Manufacturer is located in a non-Code state or province, insert the name of thestate or province where the Inspector took his original examination to obtain his National Board Commission, providedhe still has a valid commission for that state or province. Otherwise, if no valid commission, show the name of thestate or province where he has a valid commission authorizing him to make the shop inspection.


F43 The Inspector’s National Board commission number must be shown when the boiler is stamped National Board; otherwiseshow only his state or province commission number.

F44 To be completed, when applicable, and signed by an authorized representative of the organization responsible for fieldassembly of the part or component into the completed boiler.

F45 Show ASME Certificate of Authorization number, kind of symbol, and date of expiration of said authorization.


F47 Indicate those items inspected in the field that were not inspected in the shop. List parts not covered elsewhere on theData Report. If insufficient space, attach a supplementary sheet (Form P-6).

F48 Show page number and total number of pages of Form P-2B.

223



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2010 SECTION I

(10)

F1

F2

F3

F4 F5 F5 F5 F5 F6

Heads or Ends

F8

F12 F12 F14

F10

F14F12F10F18

F12F11F10F17

F10F18F11F10F20F19

F20 F10 F11 F12 F12F18 F10 F14 F15 F16 F10F19

F7

F10

F10

F15 F10F16

F11 F12 F13

F11 F12

F14

F9

FORM P-3 MANUFACTURER’S DATA REPORT FOR WATERTUBE BOILERS, SUPERHEATERS,

WATERWALLS, AND ECONOMIZERS


MASTER DATA REPORT YES




4. Unit identification

6(a). Drums

InsideDiameter

Effi-ciency

Effi-ciency

Radiusof Dish

Hydro-staticTest

ManholesNo. Size

Material Spec. No.,Grade

Circum.Joints

MaterialSpec. No.

MaterialSpec. No.

MaterialSpec. No.

Hydro.Test

Diameter

LongitudinalJoints

No. &type

No. &type*

Material Spec. No.,Grade

Longitu-dinal

Circum-ferential

Tube Hole LigamentEfficiency, %

No.

123

No.

No. Size and Shape Thickness Thickness ThicknessDiameter

Heads or Ends

Shape

Thickness Type**1

*Indicate if (1) Seamless; (2) Fusion welded.

6(e). Mud Drum

7(a). Waterwall Headers

8(a). Economizer Headers

Hydro. test

7(b). Waterwall Tubes

8(b). Economizer Tubes

or

23

Inside Length Thickness Inside Radius

Heads

Inside Radius

Shell Plates Tubesheets

5. The chemical and physical properties of all parts meet the requirements of material specifications of the ASME BOILER AND PRESSURE VESSEL CODE. The design, construction, and workmanship conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE ,

.

ID Nos.(Manufacturer’s Serial No.)

Addenda to

Supporting Manufacturer’s Data Reports properly identified and signed by Commissioned Inspectors are attached for the following items of this report:

(if applicable), and Code Cases(Numbers)(Date)

MAWPNet AreaPitch

6(d). Staybolts

6(c). Headers No.

**Indicate if (1) Flat; (2) Dished; (3) Ellipsoidal; (4) Hemispherical.

or

Heads or Ends Hydro. Test

(For sect. header boilers. State Size; Shape;Material spec. no.; Thickness)

(Shape; Material spec. no.; Thickness)

(Material spec. no.; Diameter; Size telltale; Net area)

(Box or sinuous or round; Material spec. no.; Thickness)

(Shape; Materialspec. no.; Thickness)

(Horizonal and Vertical) (Supportedby one bolt)

(Complete boiler, superheater,waterwall, economizer, etc.)

(Drawing No.) (Year built)(Nat’l. Board No.)(CRN)

(Year)

Material Spec. No., GradeThickness

Thickness

(Name of part, item number, manufacturer’s name, and identifying stamp)

(Check one) NO

(07/10)

6(b). Boiler Tubes

224



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2010 SECTION I

F24

F22 F23 F22 F23

F23F22 F22 F23

F10F16F15F14F10F12F12F11F10F20F19 F18

F21

F26

F27

F28

F29

F30

F32F32F32

F25 F25 F25

F31

F36

F5 F5 F5 F5

FORM P-3



Our Certificate of Authorization No. to use the (S) Symbol expires .

Date Signed Name

MaterialSpec. No.

Maximum AllowableWorking Pressure

Shop Hydro.Test

HeatingSurface Heating surface to

be stamped on drum heads.This heating surface not to be used for determining minimum pressure relief valve capacity.

Code Par. and/orFormula on Which

MAWP Is Based

MaterialSpec. No.

MaterialSpec. No.

Hydro.Test

9(b). Superheater Tubes

10(a). Other Parts (1)

9(a). Superheater Headers

11. Openings (1) Steam

14. Maximum Designed Steaming Capacity

15. Remarks

12.13. Field Hydro.

Test

(2) (3) 10(b). Tubes for Other Parts

1

a

b

c

e

d

Boiler

Waterwall

Economizer

Other Parts

Superheater

2

3

Size and Shape ShapeNo. Thickness Thickness ThicknessDiameter

Heads or Ends


(No., size, and type of nozzles or outlets)

(Manufacturer)

Boiler made by

Our Certificate of Authorization No. to use the (A) or (S) Symbol expires

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the state or province of

and employed by

have inspected parts of this boiler referred to as data items

and have examined Supporting Manufacturer’s Data Reports for items

and state that, to the best of my knowledge and belief, the Manufacturer has

at .

.




(3) Blowoff(No., size, and type of nozzles or outlets)


(No., size, type, and location of connections)(4) Feed

We certify that the statements made in this data report are correct and that all details of design, material, construction, and workmanship of this boiler

conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

constructed this boiler in accordance with Section I of the ASME BOILER AND PRESSURE VESSEL CODE.


Manufacturer’s Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage

or a loss of any kind arising from or connected with this inspection.

We certify that the field assembly of all parts of this boiler conforms with the requirements of Section I of the ASME BOILER AND PRESSURE VESSEL

CODE.

(04/09)

(2) Pressure Relief Valve


225



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2010 SECTION I

F33

F27

F34

F30

FORM P-3



and belief, the Manufacturer and/or the assembler has constructed and assembled this boiler in accordance with the applicable sections of the ASMEBOILER AND PRESSURE VESSEL CODE. The described boiler was inspected and subjected to a hydrostatic test of psi.

and employed by

have compared statements in this Manufacturer's Data Report with the described boiler and state that the parts referred to as data items, not included in the Certificate of Shop Inspection, have been inspected by me and that, to the best of my knowledge



Manufacturer’s Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage

or a loss of any kind arising from or connected with this inspection.

(03/07)

F5 F5 F5 F5Boiler No.(Mfr’s. Serial No.) (CRN) (Drawing No.) (Nat’l Board No.)

226



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2010 SECTION I

(10)

F1 Name and address of Manufacturer, i.e., maker of all components not covered by Supporting Data Reports.


F3 Name and address of location where boiler is to be installed. If not known, so indicate (e.g., “Not known—built forstock”).

F4 Name the unit documented by this Data Report. Note that this report may cover a complete boiler unit or separatecomponent items (e.g., superheaters and economizers) fabricated by a manufacturer other than the Manufacturer ofthe boiler unit.

F5 Identification of boiler by applicable numbers. If intended for installation in Canada, indicate the Canadian DesignRegistration Number and drawing number. To be shown on all pages of Form P-3.



F8 Issue date of Addenda (if applicable) to Section I under which boiler was constructed (e.g., “1990”).

F9 To be completed when one or more components comprising the boiler are furnished by others, and supported by DataReports such as Forms P-3 and P-4, as appropriate. Use Form P-5 or P-6 if necessary.


F11 Nominal thickness of the plate.

F12 Minimum thickness after forming.

F13 Radius on concave side of dish.

F14 Shop hydrostatic test, if any, applied to individual part prior to test applied to the assembled boiler (see Lines 12 and 13).

F15 Outside diameter

F16 Minimum thickness of tubes.

F17 This space for headers not covered on Lines 7(a) through 10(a). It is intended primarily for sectional headers on straighttube watertube boilers.

F18 Indicate shape as flat, dished, ellipsoidal, or hemispherical.

F19 Use inside dimensions for size.

F20 Indicate shape as square, round, etc.


F22 Size is nominal pipe size.





A-352 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT, FORM P-3 (See PG-112.2.2)


chosen unit.

227



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2010 SECTION I

F28 Indicate the Data Items covered on Form P-3 on Lines 6 through 14.

F29 Indicate by Line numbers those items furnished by others for which Supporting Data Reports have been examined.

F30 The Inspector’s National Board commission numbermust be shown when the boiler is stamped National Board; otherwiseshow only his state or province commission number. (See F27 above.)

F31 To be completed, when applicable, and signed by an authorized representative of the organization responsible for fieldassembly of the boiler.



F34



National Board Stamped Boilers and Pressure Vessels (see Form P-3, Line 4After “and/or State or Province” in the certification blocks —



Indicate those items on Lines 6 through 14 of Form P-3 inspected in the field that were not inspected in the shop.


228



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2010 SECTION I

(10)

F1

F2

F3

F4 F4

F5

F4F4

F7

F8

F9

F10

F11

F4

F6

FORM P-3A ENGINEERING-CONTRACTOR DATA REPORT FOR A COMPLETE BOILER UNIT

As Required by the Provisions of the ASME Boiler and Pressure Vessel Code Rules, Section I

2. Purchaser

1. Engineering-Contractor

3. Type of Boiler

4. Boiler Number

5. The design of this boiler complies with Section I of the ASME BOILER AND PRESSURE VESSEL CODE , Addenda to

6. Design specification for complete boiler unit — list components with their pressure and temperature (use separate sheet if necessary).

7. Maximum Designed Steaming Capacity lb/hr

(if applicable), and Code Cases .

CERTIFICATE OF COMPLIANCE

CERTIFICATION OF ENGINEERING-CONTRACTOR

We certify the statements in this report to be correct.

Date

Signed(Authorized Representative)

NameEngineering Contractor [(S) Stamp holder]

Certificate of Authorization no. Expires

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the State or Province of

and employed by

of

Date

Commissions(Authorized Inspector) [National Board (incl. endorsements), State, Province, and no.]

have examined the design specification as described in Item 6 and state that, to the best of my knowledge and belief, the Engineering-Contractor has provided for the construction of a complete boiler unit in accordance with the applicable sections of the ASME BOILER AND PRESSURE VESSEL CODE.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the boiler described in this Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this certification.

(Name and address)

(Name and address)

(CRN)(Engineer-Contractor’s Serial no.)

(Date)

(Drawing No.)

(Numbers)

(National Board No.) (Year built)

(Year)

(07/10)

229



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2010 SECTION I

F13 F13

F12

F14

F10

F11

F15

F12

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the boiler described in this Manufacturer's Data Report. Furthermore, neither the inspector nor his employer shall be liable in any manner for any personal injury or property damage or a loss of any kind arising from or connected with this inspection.

FORM P-3A


We certify that the field assembly construction of all parts of this boiler conforms with the requirements of Section I of the ASME BOILER ANDPRESSURE VESSEL CODE.

Our Certificate of Authorization no. to use the “A” or “S” Symbol expires




and employed by

of have compared statements in this Manufacturer's Data Report with the described boiler and state that the parts referred to as data items , not included in the Certificate of Shop Inspection, have been inspected by me and that, to the best of my knowledge and belief, the Manufacturer and/or assembler has constructed and assembled this boiler in accordance with the applicable sections of the ASME BOILER AND PRESSURE VESSEL CODE. The described boiler was inspected and subjected to a hydrostatic test

of psi.

Date

Commissions(Authorized Inspector) [National Board (incl. endorsements), State, Province, and no.]

(03/07)

F4 F4 F4 F4Boiler No.(Mfr’s. Serial No.) (CRN) (Drawing No.) (Nat’l Board No.)

230



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2010 SECTION I

(10)A-353 GUIDE FOR COMPLETING ENGINEERING-CONTRACTOR DATA REPORT FOR A COMPLETE

BOILER UNIT, FORM P-3A (See PG-112.2.3)

F1 Name and address of Engineering-Contractor who has assumed the Manufacturer’s Code responsibility for the designspecifications of the complete boiler unit.


F3 Show type of boiler documented by this report (e.g., “Steam watertube with superheat and reheat elements”).

F4 Identification of boiler by applicable numbers and year of manufacture. To be shown on all pages of Form P-3A.

F5 Date (year) of Section I Edition to which boiler was designed.

F6 Issue date of Addenda (if applicable) to which boiler was designed (e.g., “1990”).

F7

F8 To be completed and signed by an authorized representative of the Engineering-Contractor named in .

F9 This certificate to be completed by an Authorized Inspection Agency representative.


National Board Stamped Boilers and Pressure Vessels (see Form P-3A Line 4)After “and/or State or Province” in the certification blocks —



F11 The Inspector’s National Board commission number should be shown when the boiler is stamped National Board;otherwise show only his state or province commission number. (See F10 above.)

F12 To be completed, when applicable, and signed by an authorized representative of the organization responsible to fieldassembly of the boiler.



F15 Indicate items inspected in the field that were not inspected in the shop. List items on back of Form P-3A or attachappropriate Data Form.

List design specification of the boiler unit in this space (e.g. "Boiler rating—200,000 lb/hr (90000 kg/hr); Economizer and steam generating section (drums, headers, and tubes) — 1,500 psi (10 MPa), 600°F (315°C); Superheater elements (headers and tubes)—1,500 psi (10 MPa), 950°F (510°C); Reheater elements (headers and tubes) —1,000 psi (6.9 MPa), 900°F (480°C).

F1


231



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2010 SECTION I

(10)

F1 F32

F9F8

F20 F21 F12 F13 F14 F22 F12 F14 F16

F10 F11

F2

F13 F33 F33

F16F15

F13F12

F12

F12F17

F13 F14

F19 F12 F13 F14

F12

F22 F12 F14

F33

F16

F7F6F5

F3

F4

F22 F12F14 F16 F17 F18 F12F12 F13 F14F21F20

FORM P-4 MANUFACTURER’S PARTIAL DATA REPORT


1. Manufactured by , P-4 ID No.(Name and address of manufacturer)

(For sect. header boilers, state: Size; Shape; Mat’l. spec. no.; Thickness) (Shape; Material spec. no.; Thickness)

(Year) (Date) (Numbers)

2. Manufactured for

6(a). Drums

3. Identification of Part(s)

, Addenda to (if applicable), and Code Cases


InsideDiameter

No. &Type*

No. &Type

Radiusof Dish

HydrostaticTest

ManholesNo. Size

Effi-ciency

Material Spec. No., GradeLongitu-

dinalCircum-ferential

Tube Hole LigamentEfficiency, %

No.

12

34

Inside Length Thickness Inside Radius Inside Radius

Shell Plates Tubesheets

Thickness

MaterialSpec. No., Grade

Material Spec. No., GradeThicknessDiameter

Thickness Type**

6(b). Boiler Tubes

*Indicate if (1) Seamless; (2) Fusion welded. **Indicate if (1) Flat; (2) Dished; (3) Ellipsoidal; (4) Hemispherical.

6(e). Mud Drum Heads or Ends

(Box or sinuous or round; Material spec. no.; Thickness)6(c). Headers No.

(Material spec. no.; Diameter; Size telltale; Net area)6(d). Staybolts

(Horizontal and vertical)Pitch

(Shape; Material spec. no.; Thickness)Heads or Ends Hydro. Test

(Supported by one bolt)Net Area MAWP

or

Hydro Test, psior

LongitudinalJoints

Circum.Joints Heads

No.

12

34

NationalBoard No.

Manufacturer’sDrawing No.

Mfr’s. IdentifyingNumbers

LineNo.Name of Part Quantity CRN

YearBuilt

7(a). Waterwall Headers 7(b). Waterwall Tubes

MaterialSpec. No.

MaterialSpec. No.

MaterialSpec. No.

Hydro.TestNo. Size and Shape Thickness ThicknessThickness Shape Diameter

Heads or Ends

4. The chemical and physical properties of all parts meet the requirements of material specifications of the ASME BOILER AND PRESSURE VESSEL CODE. The design (as indicated on line 14, Remarks), construction, and workmanship conform to ASME Rules, Section I of ASME BOILER AND

PRESSURE VESSEL CODE.

Effi-ciency

(07/10)

232



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2010 SECTION I

F27

F18F17F16F12F14F14F13F12F20 F21 F22

F23 F24 F25

F28

F29

F30

F24 F25

F24

F33

F33

F26 F34

F25 F24 F25

F31

F12

F32

FORM P-4


CERTIFICATE OF INSPECTION

to use the (PP) or (S) Symbol expires .

Date Signed Name

MaterialSpec. No.

Maximum AllowableWorking Pressure Hydro. Test

HeatingSurface

Heating surface to bestamped on drum heads.

This heating surface not tobe used for determiningminimum pressure reliefvalve capacity.

Code Para. and/orFormula on Which

MAWP Is Based

MaterialSpec. No.

MaterialSpec. No.

Hydro.Test

9(a). Superheater Headers

8(a). Economizer Headers

9(b). Superheater Tubes

8(b). Economizer Tubes

11. Openings (1) Steam

12.

(2) Pressure Relief Valve

10(a). Other Parts (1) 10(b). Tubes for Other Parts(2)

14. Remarks

a

b

c

e

d

Boiler

Waterwall

Economizer

Other Parts

Superheater

Size and Shape ShapeNo. Thickness

or

Thickness ThicknessDiameter

Heads or Ends



(Manufacturer)

I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and/or the State orProvince of

, and state that, to the best of my knowledge and belief, the Manufacturer has constructed

and employed by

Report on


1

2

3


(3) Blowoff (4) Feed(No., size, and type of nozzles or outlets) (No., size, type, and location of connections)

(3)

We certify the statements made in this Manufacturer’s Partial Data Report to be correct and that all details of design (as indicated on line 14,

Remarks), material, construction, and workmanship of this boiler part conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

this part in accordance with the applicable sections of the ASME BOILER AND PRESSURE VESSEL CODE.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the part described in this

Manufacturer’s Partial Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or


have inspected the part of the boiler described in this Manufacturer’s Partial Data

(04/09)


P-4 ID No.

233



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2010 SECTION I

(10) A-354 GUIDE FOR COMPLETING MANUFACTURER’S PARTIAL DATA REPORT, FORM P-4 (See PG-112.2.4)


chosen units.

F1 Name and address of manufacturer of the part(s) reported on the Form P-4.

F2 Name and address of Manufacturer of the boiler unit with which the part(s) will be used, if known. If built for stock, sostate. If for an existing unit, name of the owner or user and address of the unit at place of installation.

F3 Identification of individual parts documented by the Form P-4.

F4 Show name of part, e.g., “steam drum,” “Superheater header,” etc.

F5 Show data Line number of Form P-4 for the named part.

F6 Show manufacturer’s serial or other numbers stamped on the named part.

F7 Show the drawing number for the named part.

F8 Where applicable, the National Board Number from the Manufacturer’s series of National Board Numbers.

F9 Year in which fabrication of the part was completed.

F10 Date (year) of Section I Edition under which part was constructed.

F11 Issue date of Addenda (if applicable) to Section I under which part was constructed (e.g., “1990”).

F12 Show the complete ASME Material Specification No. and Grade as listed in the appropriate stress allowance table inthe Appendix of Section I (e.g., “SA-285-B”). Exception: A specification number for a material not identical to an ASMESpecification may be shown only if such material meets the criteria in the Foreword of this Section. When material isaccepted through a Code Case, the applicable Case Number shall be shown.

F13 Nominal thickness of the plate.

F14 Minimum thickness after forming.

F15 Radius on concave side of dish.

F16 Hydrostatic test, if any, applied to individual part prior to test applied to the assembled boiler.

F17 Outside diameter.

F18 Minimum thickness of tubes.

F19 This space for headers not covered in Lines 7(a) through 10(a). It is intended primarily for sectional headers on straighttube watertube boilers.

F20 Use inside dimensions for size.

F21 Indicate shape as square, round, etc.

F22 Indicate shape as flat, dished, ellipsoidal, or hemispherical.


F24 Size is nominal pipe size.


F26 Any additional information to clarify the report should be entered here. When applicable and when it is known, indicatethe National Board Number of the completed boiler.

F27 To be completed and signed by an authorized representative of the part(s) manufacturer.

F28 This certificate to be completed by the Authorized Inspection Agency representative who performs the inspection.a National Board Number has been assigned to the part, the inspector signing this certificate must hold a valid NationalBoard Commission.


National Board Stamped Boiler and Pressure Vessel Parts (see Form P-4 Line 3)After “and/or State or Province” in the certification blocks —

If the Inspector has a valid commission for the state or province where the manufacturer’s shop is located, insert thename of that state or province. If the Manufacturer is located in a non-Code state or province, insert the name of thestate or province where the Inspector took his original examination to obtain his National Board Commission, providedhe still has a valid commission for that state or province. Otherwise, if no valid commission, show the name of thestate or province where he has a valid commission authorizing him to make the inspection.

Boiler and Pressure Vessel Parts Not Stamped National BoardFollow the above procedure. However, in this case, do not list any National Board Commission number after theInspector’s signature at the bottom of the block.

If

234



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2010 SECTION I

F30 The Inspector’s National Board commission number should be shown if it is known that the part is to be used on acompleted boiler that is to be stamped National Board or if a National Board Number has been assigned to the part;otherwise show only his state or province number (see F29 above).


F32 The Certificate Holder shall assign a unique identifying number for this form. To be shown on all pages of Form P-4.

F33 Indicate data, if known.

F34 Indicate extent of design function [see PG-112.2.4(c)].


235



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2010 SECTION I

F

F

F

1 F1 F23

2 F2

3 F3a

F9

F4a

F5 F5 F6

F8

F10

F7

F11F11

F13

F15

F11

F12 F12

F14

F12

F4

FORM P-4A MANUFACTURER’S DATA REPORT FOR FABRICATED PIPING




(Name and address of purchaser)2. Manufactured for

(Main steam, boiler feed, blow-off, or other service piping — state which)4. Identification

(Pressure)

(Date)

(Temperature) (Name of Co.)

(Numbers)

(Year)

5. Design Conditions of Piping

8. Shop Hydrostatic Test

9. Remarks

.

7. Description of Piping (include material identifications by ASME specification or other recognized Code designation)

Code Design by

Addenda to (if applicable), and Code Cases

. Specified by

.

.

Piping Registration No.

Order No. P-4A ID No.

Order No.

3. Location of installation Boiler Registration No.

(Manufacturer or Fabricator) (Authorized Representative)Date

Date

Signed by




of and employed by

have inspected the piping described in this Manufacturer’s Data Report and state that, to the best of my knowledge and

belief, the manufacturer has constructed this piping in accordance with the applicable sections of the ASME BOILER AND PRESSURE VESSEL CODE.

to use the (S) or (PP) Symbol Expires .

(Authorized Inspector) [Nat’l Board (incl. endorsements), State, Province, and No.]Commissions

(07/10)

We certify the statement in this data report to be correct and that all details of design, material, construction, and workmanship of the described

piping conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE.

By signing this certificate, neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the piping described in

this Manufacturer’s Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or


6. The chemical and physical properties of all piping meet the requirements of material specifications of the ASME BOILER AND PRESSURE VESSEL

CODE. The construction and workmanship conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE

236



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2010 SECTION I

F16

F18

F17

F18

F19

F18

F20

F18

F15

F14

F21

F22

F18

F19

F19 F19

F18F18

F18

FORM P-4A


10. Description of Field Fabrication

11. Field Hydrostatic Test .

(Authorized Representative) (Assembler)Date

Date

Signed Name



of and employed by

, not included in the Certificate of Shop Inspection, have been inspected by me and that, to the

have compared the statements in this Manufacturer’s Data Report with the described piping and state that the parts referred to as Data

.


of .

Items

(03/07)

We certify that the field assembly of the described piping conforms with the requirements of Section I of the ASME BOILER AND PRESSURE

VESSEL CODE. Our Certificate of Authorization No.

best of my knowledge and belief, the manufacturer and/or assembler has constructed and assembled this piping in accordance with the applicable

sections of the ASME BOILER AND PRESSURE VESSEL CODE. The described piping was inspected and subjected to a hydrostatic test

CERTIFICATE OF FIELD FABRICATION COMPLIANCE

(Authorized Representative) (Fabricator)Date Signed Name

Our Certificate of Authorization No. to use the (S) or (PP) Symbol expires

to use the (A), (S), or (PP) Symbol expires

.

We certify the statement in this data report to be correct and that all details of design, material, construction, and workmanship of the described

piping conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE.


this Manufacturer’s Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or


F23P-4A ID No.

237



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2010 SECTION I

A-354.1 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT, FORM P-4A (See PG-112.2.5)

F1 Name and address of manufacturer or fabricator of Code piping including order identifying number.

F2 Name and address of purchaser and/or owner and his identifying order number.

F3 Name and address of location where piping is to be installed, if known.

F3a Include the registration number of the boiler where the piping is to be installed, if known (e.g., National Board No.,Canadian Design Registration No., or other jurisdictionally required registration numbers).

F4 Identify each section of boiler external piping (e.g., main steam, blow-off, boiler feed), including the section’s

F4a Include the piping registration number, if assigned (e.g., National Board No., Canadian Design Registration No., or otherjurisdictionally required registration numbers).

F5 Show the maximum design pressure and temperature of the section of pipe (see ASME B31.1).

F6 Name of the organization that established the design pressure and temperature.

F7 The organization that made the calculations and selected the pipe schedules for the working conditions.

F8 Refer to the requirements of ASME B31.1.

F9 Describe each section of piping, size, thickness, schedule, etc. Show the complete ASME Material Specification No. andGrade as listed in the appropriate stress allowance table in the Appendix of Section I (e.g., “SA-106”). Exception: Aspecification number for a material not identical to an ASME Specification may be shown only if such material meetsthe criteria in the Foreword of this Section. When material is accepted through a Code Case, the applicable Case numbershall be shown. Identify the organization that will receive this piping and the identification number of the boiler.

F10 Piping fabricated in a shop show test pressure if hydro-applied in the shop (see PG-99) and witnessed by AuthorizedInspector.

F11 The name of the piping manufacturer or fabricator, signature of authorized representative and date signed.

F12 Show ASME Authorization number, kind of symbol, and date of expiration.


F14 To determine what goes in this space, you should be guided by the following:

National Board Stamped Fabricated Piping (see Form P-4A Line 4)After “and/or State or Province” in the certification blocks —


Fabricated Piping Not Stamped National BoardFollow the above procedure. However, in this case do not list any National Board Commission number after theInspector’s signature at the bottom of the block.

F15 The Inspector’s National Board commission number must be shown when the fabricated piping is stamped NationalBoard; otherwise, show only his/her state or province commission number (See above).

F16 Describe sections of piping to be joined, design of welded joint, procedure to be followed, number passes, preheat,postheat, etc. (see ASME B31.1).

F17 Show test pressure used during field hydrostatic test (see PG-99) and witnessed by the Authorized Inspector.

F18 Signed by an authorized representative of the organization responsible for the field fabrication or field assembly(assembler, manufacturer, fabricator), or both, and the date signed.

F19 Show ASME authorization number, kind of symbol, and date of expiration.


F21 Only list those piping sections and welds inspected in the field.

F22 Show field hydrostatic test pressure (see PG-99).

F23 The Certificate Holder shall assign a unique identifying number for this Form. To be shown on all pages of Form P-4A.

F14


chosen unit.

identification number, if assigned.


238



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2010 SECTION I

(10)

F13

F12

F17

F14

F16

F12

F15

F11

F1 F1

F2

F18

F2

F3 F3a

F4 F4a

F5 F5 F6

F9

F10

F7

F8

F12

in this Manufacturer’s Data Report with the described piping and state that the parts referred to as Data Items have been

inspected by me and that, to the best of my knowledge and belief, the manufacturer and/or assembler has assembled this piping in accordance

with the applicable sections of the ASME BOILER AND PRESSURE VESSEL CODE. The described piping was inspected and subjected to a


(Authorized Representative) (Assembler)Date

Date

Signed Name



of and employed by have compared the statements

.


test of .

(07/10)

We certify that the field assembly of the described piping conforms with the requirements of Section I of the ASME BOILER AND PRESSURE

VESSEL CODE. Our Certificate of Authorization No. to use the (A), (S), or (PP) Symbol expires


this Manufacturer's Data Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or


6. The chemical and physical properties of all piping meet the requirements of material specifications of the ASME BOILER AND PRESSURE

VESSEL CODE. The construction and workmanship conform to Section I of the ASME BOILER AND PRESSURE VESSEL CODE

FORM P-4B MANUFACTURER’S DATA REPORT FOR FIELD INSTALLED MECHANICALLY ASSEMBLED PIPING


1. Manufactured by Order No.

Order No.

,

P-4B ID No.(Name and address of manufacturer)

(Main steam, boiler feed, blow-off, or other service piping — state which)

2. Manufactured for

3. Location of Installation Boiler Registration No.

4. Identification

Addenda to

Piping Registration No.


Specified by5. Design Conditions of Piping .

7. Description of Piping (include material identifications by ASME specification or other recognized Code designation)

8. Field Hydrostatic Test .

(Pressure) (Temperature)

Code Design by

(Name of Co.)

(Year)(if applicable), and Code Cases

(Numbers)

9. Remarks

(Date)

239



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2010 SECTION I

A-354.2 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT, FORM P-4B (See PG-112.2.5)

F1 Name and address of manufacturer or fabricator of Code piping including order identifying number.

F2 Name and address of purchaser and/or owner and his identifying order number.

F3 Name and address of location where piping is to be installed, if known.

F3a Include the registration number of the boiler where the piping is to be installed, if known (e.g., National Board No.,Canadian Design Registration No., or other jurisdictionally required registration numbers).

F4 Identify each section of piping (e.g., main steam, blow-off, boiler feed), including the section’s identification number,if assigned.

F4a Include the piping registration number, if assigned (e.g., National Board No., Canadian Design Registration No., or otherjurisdictionally required registration numbers).

F5 Show the maximum design pressure and temperature of the section of pipe (see ASME B31.1).

F6 Name of the organization that established the design pressure and temperature.

F7 The organization that made the calculations and selected the pipe schedules for the working conditions.

F8 Refer to the requirements of ASME B31.1.

F9 Describe each section of piping, size, thickness, schedule, etc. Show the complete ASME Material Specification No. andGrade as listed in the appropriate stress allowance table in the Appendix of Section I (e.g., “SA-106”). Exception: Aspecification number for a material not identical to an ASME Specification may be shown only if such material meetsthe criteria in the Foreword of this Section. When material is accepted through a Code Case, the applicable Case numbershall be shown.

F10 Piping fabricated in field show test pressure of hydro-applied in the field (see PG-99) and witnessed by AuthorizedInspector.

F11 Signed by an authorized representative of the organization responsible for the field assembly and hydrostatic test.

F12 Show ASME authorization number, kind of symbol, and date of expiration.


F14 To determine what goes in this space, you should be guided by the following:

National Board Stamped Fabricated Piping (see Form P-4B Line 4)After “and/or State or Province” in the certification blocks —


Fabricated Piping Not Stamped National BoardFollow the above procedure. However, in this case do not list any National Board Commission number after theInspector’s signature at the bottom of the block.

F15 Only list those piping sections inspected in the field.

F16 Show test pressure used during field hydrostatic test (see PG-99) and witnessed by the Authorized Inspector.

F17 The Inspector’s National Board commission number must be shown when the fabricated piping is stamped NationalBoard; otherwise, show only his state or province commission number.

F18 The Certificate Holder shall assign a unique identifying number for this Form. To be shown on all pages of Form P-4B.


chosen units.

240



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2010 SECTION I

(10)

F1

F2

F12

F10

F11

F3

F4

F6

F5

F7 F8 F9

FORM P-5 SUMMARY DATA REPORT FOR PROCESS STEAM GENERATORS


1. Manufacturer (or Engineering-Contractor)(Name and address)

2. Purchaser

7. Remarks


(Name and address)


Signed Name

Commissions

to use the (S) Symbol expires

, Addenda to (if applicable), and Code Cases .

.

(Date)(Year) (Numbers)

3. Location of Installation(Name and address)

4. Type of Boiler

5. Boiler No.

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

(CRN)(Mfr’s. serial)

(Authorized Representative) (Mfr. or Eng. Contractor)

(Authorized Inspector) [Nat’l Board (incl. endorsements), State, Province, and No.]

(Drawing No.) (Year built)(Nat’l. Brd. No.)

6. Data Reports Attached

No. Name of Part Part Manufacturer Identifying Numbers Data Report Form

(07/10)

We certify the statements of this Summary Data Report, with the attached certified data reports as listed, provide documentation that the design,

construction, materials and workmanship of the complete boiler unit to conform to the ASME Rules, Section I of the ASME BOILER AND PRESSURE

VESSEL CODE

241



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2010 SECTION I

(10) A-355 GUIDE FOR COMPLETING SUMMARY DATA REPORT FOR PROCESS STEAM GENERATORS,

FORM P-5 (See PG-112.2.6)

F1 Name and address of the Manufacturer or Engineering-Contractor, whichever is responsible for the complete boilerinstallation.

F2 Name and address of the purchaser and/or owner.

F3 Name and address of location where boiler is installed.

F4 Indicate type of boiler (e.g., “Steam Watertube — Drum Type”).

F5

F6 Show name of part, e.g., “Steam Drum,” “Waterwall Header,” etc.

F7 Name of the manufacturer of the named part.

F8 Show manufacturer’s serial number and other numbers stamped on the named part.

F9 List Manufacturer’s Data Report Form number (e.g., “P-4”).

F10 To be completed and signed by an authorized representative of the Manufacturer or Engineering-Contractor namedin F1 .


F12 Issue date of most recent Addenda (if applicable) to Section I under which boiler was constructed

(e.g., “Summer 1972”).

In this section list all parts covered by the various Data Report Forms, P-2, P-3, P-3A, P-4, or P-4A. Use Supplementary sheet (Form P-6) if necessary. A copy of each Data Form shall be securely attached to Form P-5.


chosen units.

242



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2010 SECTION I

FORM P-6 MANUFACTURER’S DATA REPORT SUPPLEMENTARY SHEET

As Required by the Provisions of the ASME Boiler and Pressure Vessel Code Rules

Data Itemsby Line No.

(Year built)

(Manufacturer’s Serial no.) (CRN) (Drawing no.) (National Board no.)

1. Manufacturer (or Engineering-Contractor)(Name and address)

2. Purchaser(Name and address)

3. Type of Boiler

4. Boiler No.

Date

(Authorized Inspector) [National Board (incl. endorsements), State, Province, and no.]Commissions

Date Signed By

(03/07)

243



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2010 SECTION I

(10)

F1 F2

F3

F4

F5 F6 F6 F6 F6

F8F7 F11 F12 F13 F14 F15F9 F10

F16 F17

F19

F21

FORM P-7 MANUFACTURER’S DATA REPORT FOR PRESSURE RELIEF VALVES


1. Boiler manufactured by , P-7 ID No.(Name and address of manufacturer)

2. Boiler manufactured for(Name and address of purchaser)


(Complete boiler, superheater, waterwall, economizer, etc.) (Mfr’s. Serial No.) (Nat’l. Board No.)(CRN) (Drawing No.)4. Unit identification ID Nos.

5. Identification of Pressure Relief Valves

* Material: (1) SA-216, WCB. (2) SA-217, WC6. (3) SA-217, WC9. (4) SA-182, F 22. (5) Other** Connector type: (A) Groove Weld. (B) Socket Weld. (C) Threaded. (D) Flanged.

6. Unit Relieving Capacity

7. Determination of Unit Relieving Capacity

Is PG-67.2.7 applicable to this boiler? No Yes

Approach taken to address capacity PG-67.2.7.1 PG-67.2.7.2

TagNo.

ServiceLocation

ManufacturerName

Design orType No.

SetPress.Conn.** Capacity

Material*

Quantity Size

(07/10)

Minimum RequiredCircuit Furnished

Boiler

Economizer

Superheater

Reheater Inlet

Reheater Outlet

Other

244



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2010 SECTION I

F18

F2

FORM P-7

(04/09)



Date Signed Name

Symbol expires .to use the (S) or (M)

(Authorized Representative) (Manufacturer)

We certify the statements of this Manufacturer’s Data Report for Pressure Relief Valves to be correct and that all details conform to Section I of

the ASME BOILER AND PRESSURE VESSEL CODE.

P-7 ID No.

245



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2010 SECTION I

(10) A-356 GUIDE FOR COMPLETING MANUFACTURER’S DATA REPORT FOR PRESSURE RELIEF VALVES,

FORM P-7 (See PG-112.2.8)

F1 Name and address of boiler Manufacturer, i.e., maker of all components not covered by supporting Data Reports orengineering contractor who has assumed the Manufacturer’s Code responsibility for the Design Specifications of thecomplete boiler unit.

F2 The Certificate Holder shall assign a unique identifying number for this form. To be shown on all pages of Form P-7.


F4 Name and address of location where boiler is to be installed. If not known, so indicate (e.g., “Not known” — built forstock).

F5 Name the unit documented by this Data Report.

F6 Identification of boiler by applicable numbers. If intended for installation in Canada, indicate the Canadian Design Registra-tion Number and drawing number.NOTE: Items F1 , F3 , F4 , F5 , and F6 shall repeat similar information on the Master Data Report.

F7 Optional — List purchaser’s or owner’s identification number assigned to valve (preferred) or tag number supplied bythe Manufacturer.

F8 Valve service location (e.g., “Boiler Drum, Superheater Outlet Header, Main Steam Piping, Cold Reheat Piping, ReheatOutlet Header, etc.”).

F9 Quantity of identical valves installed at valve service location.

F10 Valve inlet size.

F11 Valve manufacturer’s name.

F12 Valve manufacturer’s figure number or other design-type designation number.

F13 Valve body material and connection type.

F14 Pressure at which pressure relief valve is set to relieve.

F15 Certified relieving capacity of the pressure relief valve.

F16 Minimum pressure relief valve relieving capacity, as required by PG-67 and PG-68.

F17


Actual pressure relief valve relieving capacity furnished at locations indicated in accordance with PG-69.2 for saturated steam service, or in accordance with PG-68.7 for superheated steam service, or in accordance with PG-69.2.3 for supercritical steam service.

F19 Show both capacities in units of lb/hr and gpm (lpm) water, see PG-110.


chosen units.


F21 Indicate whether PG-67.2.7 is applicable to the boiler and if it is, which approach has been taken to address the additionalcapacity.

246



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2010 SECTION I

A-357 GUIDE TO DATA REPORT FORMS DISTRIBUTION

Data Report Forms Required for Section I Construction

Data Report Forms Required

Example P-2 P-2A P-3 P-3A P-4 P-4A P-4B P-5 Remarks

1 X X P-4B is submitted to authorities separately by the stamp holder assum-ing responsibility for the hydrostatic test.

2 X X P-4A is submitted to authorities separately by piping contractor.

3 X X X P-4A is submitted to authorities separately by piping contractor.

4 X X P-3 is also Master Data Report.

5 X X P-3 is also Master Data Report.

6 X X X X P-3 or P-4 is required for each manufacturer supplying major compo-nent. Assembler completes field assembly portion of P-3A. P-3Asubmitted by Engineering-Contractor is also Master Data Report.

7 X P-4A is not required since all work comprising Code responsibility isdone by one contractor.

8 X Appropriate portion of P-2A is completed by manufacturer of boilerpressure vessel. Shop inspection block is completed by boiler pres-sure vessel manufacturer’s Authorized Inspector. Electric boiler Man-ufacturer completes the balance of P-2A.

9 X X X X X X P-2, P-3, or P-4 is required for each Manufacturer supplying majorcomponent. Assembler completes field assembly portion of P-3A.Summary Data Report P-5 submitted by Engineering-Contractor.P-3A submitted by Engineering-Contractor is also Master DataReport.

Example 1 Boiler Manufacturer supplies shop-assembled firetube boiler without piping. Piping contractor, not responsibleto boiler Manufacturer, supplies and installs threaded piping.

Example 2 Boiler Manufacturer supplies shop-assembled firetube boiler without piping. Piping contractor (“PP” stampholder) not responsible to boiler Manufacturer, supplies and installs welded piping.

Example 3 Boiler Manufacturer supplies shop-assembled watertube boiler. He subcontracts boiler drums to another manu-facturer. External piping (welded) is subcontracted to a piping contractor.

Example 4 Boiler Manufacturer supplies field-assembled watertube boiler. Field assembly is subcontracted to a contractor(“A” stamp holder) and external piping (welded) is subcontracted to a piping contractor (“PP” stamp holder).

Example 5 Boiler Manufacturer supplies and erects field-assembled watertube boiler. Owner contracts with piping contrac-tor (“PP” stamp holder) for supply and installation of piping (welded).

Example 6 Engineering-Contractor designs boiler. Several manufacturers supply component parts, such as boiler drum,tubes, superheater, economizer. In addition, a contractor holding a “PP” stamp supplies headers to superheatermanufacturer. A contractor holding an “A” stamp performs the field assembly. A piping contractor suppliesand installs boiler piping (welded).

Example 7 Boiler Manufacturer supplies and installs field-assembled boiler, including boiler piping (welded).

Example 8 Electric boiler Manufacturer holding an “E” stamp completes assembly of piping and appurtenances (nowelding). Boiler pressure vessel manufactured by “S” or “M” stamp holder.

Example 9 Engineering-Contractor designs a process steam generator consisting of several arrays of heat exchangesurface. Several manufacturers supply component parts. A contractor holding an “A” stamp performs fieldassembly. A piping contractor holding a “PP” stamp supplies and installs boiler piping (welded).

Example 10 Manufacturer holding an "S" stamp designs, manufactures, and shop assembles an electric superheater or reheater as an independent "Stand alone" pressure vessel.

X P-2B is required for electric superheaters and reheaters.10

247



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2010 SECTION I

1

2 3 4 5 6 7 8 9 10

14

15 16

1817 18

11 12 13

FORM P-8 MANUFACTURER’S OR ASSEMBLER’S CERTIFICATE OF CONFORMANCE FOR PRESSURE RELIEF VALVES



1. Manufactured (or assembled) by

I.D. # Date

2. Table of Code symbol stamped items

3. Remarks

By the signature of the Certified Individual (CI) noted above, we certify that the statements made in this report are correct and that alldetails for design, material, construction, and workmanship of the pressure relief valves conform with the requirements of Section Iof the ASME BOILER AND PRESSURE VESSEL CODE.

V Certificate of Authorization No. Expires

Date Signed(Responsible Representative) (Manufacturer or Assembler)

Name

Cert. # Qty. Type SizeSet

Pressure Capacity Test FluidDateCode CI Name CI Signature

(03/07)

248



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2010 SECTION I

A-358 GUIDE FOR THE PREPARATION OF MANUFACTURER’S OR ASSEMBLER’SCERTIFICATE OF CONFORMANCE FORM P-8

Any quantity to which units apply shall be entered on the Manufacturer’s Data Reportwith the chosen units.

NoteNo. Instruction

F1 Name and address of Manufacturer or Assembler.

F2 Pressure relief valve Manufacturer’s or Assembler’s unique identification such as serial number,work order number, or lot number.

F3 The date of completion of production of the pressure relief valve.

F4 The NB Certification Number.

F5 The quantity of identical valves for this line item.

F6 The Manufacturer’s Design or Type Number as marked on the nameplate.

F7 The inlet size of the pressure relief valve.

F8 The nameplate set pressure of the pressure relief valve.

F9 The nameplate capacity of the pressure relief valve.

F10 The fluid used for testing the pressure relief valve.

F11 The year built or the pressure relief valve Manufacturer’s or Assembler’s date code.

F12 The name of the Certified Individual.

F13 The signature of the Certified Individual. Required for each line item.

F14 Include any applicable remarks (referencing the identification number) that may pertain, such asidentification of a Code Case that requires marking on the device.

F15 The number of the pressure relief valve Manufacturer’s or Assembler’s Certificate of Authorization.

F16 Expiration date of the pressure relief valve Manufacturer’s or Assembler’s Certificate of Authori-zation.

F17 Date signed by the pressure relief valve Manufacturer’s or Assembler’s responsible representative.

F18 The Certificate of Shop Compliance block is to show the name of the Manufacturer or Assembleras shown on his/her ASME Code Certificate of Authorization. This should be signed in accordancewith the organizational authority defined in the Quality Control System.

249



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2010 SECTION I

CODES, STANDARDS, AND SPECIFICATIONS REFERENCED IN TEXT

A-360 REFERENCED STANDARDS

Specific editions of standards referenced in this Section are shown in Table A-360. It is not practical to refer to aspecific edition of each standard throughout the text, so edition references are centralized here. Table A-360 will berevised at intervals and reissued as needed.

250



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2010 SECTION I

TABLE A-360CODES, STANDARDS, AND SPECIFICATIONS REFERENCED IN TEXT

ASME StandardsB1.20.1-1983 (R2001) Pipe Threads, General Purpose (Inch)B16.1-2005 Gray Iron Pipe Flanges and Flanged Fittings (Classes 25, 125, and 250)B16.3-2006 Malleable Iron Threaded Fittings, Classes 150 and 300B16.4-2006 Gray Iron Threaded Fittings, Classes 125 and 250B16.5-2009 Pipe Flanges and Flanged FittingsB16.9-2007 Factory-Made Wrought Buttwelding FittingsB16.11-2005 Forged Fittings, Socket-Welding and ThreadedB16.15-2006 Cast Copper Alloy Threaded Fittings: Classes 125 and 250B16.20-2007 Metallic Gaskets for Pipe Flanges: Ring-Joint, Spiral-Wound, and JacketedB16.24-2006 Cast Copper Alloy Pipe Flanges and Flanged Fittings: Class 150, 300, 600, 900, 1500,

and 2500B16.25-2007 Buttwelding Ends [Note (4)]B16.34-2004 Valves — Flanged, Threaded, and Welding EndB16.42-1998 Ductile Iron Pipe Flanges and Flanged Fittings, Classes 150 and 300B31.1-2007 Power Piping [Notes (1) through (3)]B36.10M-2004 Welded and Seamless Wrought Steel PipeQAI-1 Qualifications for Authorized Inspection

ASTMA 126-2004 Standard Specification for Gray Iron Castings for Valves, Flanges, and

Pipe FittingsB 139-2001 Standard Specification for Phosphor-Bronze Rod, Bar, and ShapesE 8-2004 Standard Test Methods of Tension Testing of Metallic MaterialsE 125-63 (R2003) Standard Reference Photographs for Magnetic Particle Indications on Ferrous CastingsE 186-98 (R2004) Standard Reference Radiographs for Heavy-Walled [2 to 41⁄2 in. (51 to 114 mm)] Steel

CastingsE 280-98 (R2004) Standard Reference Radiographs for Heavy-Walled [41⁄2 to 12 in. (114 to 305 mm)] Steel

CastingsE 446-98 (R2004) Standard Reference Radiographs for Steel Casings up to 2 in. (51 mm) in Thickness

ASME Performance Test CodePTC 25-2001 Pressure Relief Devices

ASNT SpecificationSNT-TC-1A-2006 Recommended Practice for Nondestructive Testing Personnel Qualification

and CertificationCP-189-2006 ASNT Standard for Qualification and Certification of Nondestructive Testing PersonnelACCP, Revision 3, November 1997 Central Certification Program

GENERAL NOTE: The issue date shown immediately following the hyphen after the number of the standard (e.g., B1.20.1-1983) is the effectivedate of issue (edition) of the standard.

NOTES:(1) The weld end transition of Fig. PG-42.1 is also acceptable.(2) The use of diverter valves under Section I reheater pressure relief valves is prohibited.(3) Paragraph 136.4.5 (A-5) is not applicable to Boiler External Piping.(4) The user is cautioned that the O.D. tolerance used to calculate the values for dimension C shown in Table 1 and Table I-1 may be different

from the tolerance listed in the applicable material specification and that machining to this dimension may reduce the wall thickness of thepipe to less than minimum wall thickness.

251

(10)



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(10)

2010 SECTION I

A-370 GUIDE TO INFORMATION APPEARING ON CERTIFICATE OF AUTHORIZATION

ITEM DESCRIPTION

① Code Symbol granted by the Society, e.g., “S,” power boiler; “M,” miniatureboiler; “E,” electric boiler; “A,” boiler assembly; “PP,” pressure piping; and“V,” boiler pressure relief valve.

② a. The name of the Manufacturer or Assembler.

b. The full street address or physical location, city, state or province, country,and zip code.

③ This entry describes the scope and limitations, if any, on use of the Codesymbol stamps, as illustrated by the following examples.

“S” Code Symbol Stamp

1. Manufacture and assembly of power boilers at the above location.2. Manufacture and assembly of power boilers at the above location and field

sites controlled by the above location.3. Design and assembly of power boilers with fabrication subcontracted to

holders of appropriate Certificates of Authorization and field assembly atfield sites controlled by the above location.

4. Design of power boilers with responsibility for compiling Code certificationand for stamping the boiler. Fabrication and assembly subcontracted toholders of appropriate Certificates of Authorization.

5. Manufacture of boiler parts at the above location.6. Manufacture of boiler parts at the above location and field sites controlled

by the above location.7. Manufacture of boiler parts at field sites controlled by the above location.

“A” Code Symbol Stamp

1. Assembly of Power Boilers at field sites controlled by the above location.

“PP” Code Symbol Stamp

1. Design, fabrication, and assembly of pressure piping.

“M” Code Symbol Stamp

1. Manufacture and assembly of miniature boilers at the above location only.

“E” Code Symbol Stamp

1. Design and assembly of electric boilers at the above location only.2. Design of electric boilers at the above location only and assembly of electric

boilers at field sites controlled by the above location.

“V” Code Symbol Stamp

1. Manufacture of pressure relief valves for power boilers at the above loca-tion only.

2. Manufacture of pressure relief valves for power boilers at the above locationonly. (This authorization does not cover welding or brazing.)

3. Assembly of pressure relief valves for power boilers at the above location.(This authorization does not cover welding or brazing.)

④ The date authorization was granted by the Society to use the Code symbolstamp indicated.

⑤ The date authorization to use the Code symbol stamp will expire.⑥ A unique Certificate number assigned by the Society.

⑦,⑧ The signatures of the current chairman and director.

252



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2010 SECTION I

FIG. A-370 SAMPLE CERTIFICATE OF AUTHORIZATION

253



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(10)

2010 SECTION I

SAMPLE CALCULATIONS FOREXTERNAL PRESSURE DESIGN

NOTE: In A-381 and A-382, referenced stress tables and external pres-sure charts are contained in Subparts 1 and 3, respectively, in SectionII, Part D.

A-381

A ring reinforced furnace is to be installed in a ScotchMarine type boiler. From the following design data, deter-mine if the furnace is satisfactory for a design pressure of150 psi (saturated steam temperature 366°F): SA-515Grade 70 plate 5⁄8 in. thick, 36 in. outside diameter, 144in. between tubesheets, 36 in. greatest distance betweenadjacent stiffening rings, stiffening rings are attached byfull penetration welds, and rings are 5⁄8 in. wide and 3 in.high. Show all calculations.

Given: ring reinforced furnace

Do p 36 in.Ls p 36 in.

p the smaller of 36 in. or 60t. 60t p60(0.625) p 37.5. Therefore, L p 36 in.(see PFT-17.6)

material p SA-515, Grade 70P p 150 psit p 0.625 in.

saturated steam temperature p 366°F

Assumesaturated steam temperature p water temperature

Hr p 3 in.T design p T water + 100°F p 366°F + 100°F

p 466°FTr p 0.625 in.

Find: Does this design meet Section I requirements?

Use: PFT-17 and PFT-51

Solve: Per PFT-51.1.2(a), determine if Do /t ≥ 10.

Calculate Do /t

where

Do p 36 in. (given)Do /t p 36/0.625 p 57.6

t p 0.625 in. (given)

Since Do /t is greater than 10, follow the procedure outlinedin PFT-51.1.2(a).

254

Step 1: Determine the ratio of L /Do and Do /t.

Calculate L /Do

where

Do p 36 in. (given)L p 36 in. (given)

L /Do p 36/36 p 1

Calculate Do /t

where

Do p 36 in. (given)Do /t p 36/0.625 p 57.6

t p 0.625 (given)

Step 2: Enter Fig. G of Section II, Part D, the value ofL /Do p 1

Step 3: Enter Fig. G of Section II, Part D, the value ofDo /t p 57.6

Find Factor A.

Factor A p 0.0031

Step 4: Enter Table 1A of Section II, Part D, for SA-515, Grade 70, at 466°F. The external pressurechart to be used is Fig. CS-2 of Section II, PartD. Enter Fig. CS-2 of Section II, Part D, andfind the intersection of 0.0031 and 466°F.

Step 5: Find Factor B.

Factor B p 13,500

Step 6: Calculate MAWP

P p4(B)

3(Do /t)

where

B p 13,500 (see Fig. CS-2 of Section II,Part D)

Do p 36 in. (given)t p 0.625 (given)

P p4(13,500)

3(36/0.625)

P p 312.50 psi

The required moment of inertiaStep 1: Calculate As

As p (Hr)(Tr)



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2010 SECTION I

where

As p (3)(0.625)p 1.875 in.2

Hr p 3 in. (given)Tr p 0.625 in. (given)

Calculate B

B pP Do

t + (As /Ls)

where

As p 1.875 in.2 (calculated)Do p 36 in. (given)Ls p 36 in. (given)P p 150 psi (given)t p 0.625 in. (given)

B p(150)(36)

0.625 + (1.875/36)

B p 7,975 psi

Steps 2and 3: Enter Table 1A of Section II, Part D, for SA-

515, Grade 70. The external pressure chart tobe used is Fig. CS-2 of Section II, Part D. EnterFig. CS-2 of Section II, Part D, and find theintersection of 7,975 psi and 466°F.

Step 4: Find Factor A.

Factor A p 0.00059

Step 5: Calculate Is

Is p(Do)

2Ls [t + (As /Ls)] A

14

where

A p 0.00059 (see Fig. CS-2 of Section II,Part D)

As p 1.875 in.2 (calculated)Do p 36 in. (given)Ls p 36 in. (given)t p 0.625 in. (given)

Is p(36)2 (36) [0.625 + (1.875/36)] (0.00059)

14

Is p 1.3313 in.4

Step 6: Calculate actual moment of inertia I

I p(Tr)(Hr

3)12

255

where

Hr p 3 in. (given)Tr p 0.625 in. (given)

I p(0.625)(3)3

12

I p 1.4062 in.

Step 7: Compare Is with I.Is (1.3313 in.4) is less than I (1.4062 in.4); there-fore, the design of this furnace does meet Sec-tion I requirements.

A-382

A combination furnace in a boiler is made up of aMorison central section whose least inside diameter mea-sured across the convex curve of the corrugations is341⁄2 in., plate thickness is 5⁄8 in. and length is 8 ft 4 in.The plain-end sections are joined by full-penetration butt-welds and measure 181⁄2 in. from weld to head attachment.These sections are 36 in. in inside diameter and have awall thickness of 3⁄4 in. What is the MAWP of this furnace?Material is SA-285C at 700°F.

Given: combination furnace

Morison Section

D p least ID + 2 p 34.5 + 2p 36.5 (see PFT-18.1)

ID p 34.5 in.L p 100 in.t p 5⁄8 in. p 0.625 in.

Plain Section

Do p ID + 2t p 36 + 2(0.75)p 37.5 in.

ID p 36 in.L p 18.5 in.

material p SA-285C at 700°Ft p 0.75

2L p 37 in. (see PFT-19.2)

Find: MAWP

Use: Morison section — PFT-18 and PFT-19; plain sec-tion — PFT-14, PFT-19, and PFT-51

Solve: Morison section, per PFT-18.1

P p Ct /D

where

C p 15,600 (see PFT-18.1)D p 36.5 in. (see PFT-18.1)t p 0.625 in. (given)

P p(15,600)(0.625)

36.5



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2010 SECTION I

P p 267 psi

Plain section, per PFT-19.2. The MAWP shall be calcu-lated in accordance with PFT-14 and PFT-51.

Per PFT-51.1.2(a), determine if Do /t ≥ 10.

Calculate Do /t

where

Do p 37.5 in. (calculated)Do /t p 37.5 /0.75 p 50

t p 0.75 (given)

Since Do /t is greater than 10, follow the procedure out-lined in PFT-51.1.2(a).Step 1: Determine the ratios L /Do and Do /t.

Calculate L /Do

where

Do p 37.5 in. (calculated)L p 37 in. (see PFT-19.2)

L /Do p 37/37.5 p 0.99

Calculate Do /t

where

Do p 37.5 in. (calculated)Do /t p 37.5 /0.75 p 50

t p 0.75 (given)

Step 2: Enter Fig. G of Section II, Part D, the valueof L /Do p 0.99

Step 3: Enter Fig. G of Section II, Part D, the valueof Do /t p 50

Find Factor A.

Factor A p 0.0039

Step 4: Enter Table A1 of Section II, Part D, for SA-285C at 700°F. The external pressure chart tobe used is Fig. CS-2 of Section II, Part D. EnterFig. CS-2 of Section II, Part D, and find theintersection of 0.0039 and 700°F.

Step 5: Find Factor B.

Factor B p 10,500

Step 6: Calculate MAWP

P p4 (B)

3 (Do /t)

where


Do p 37.5 in. (calculated)

256

t p 0.75 (given)

P p4 (10,500)

3 (37.5 /0.75)

P p 280 psi in plain section

MAWP is 267 psi based on Morison section.

A-383

What wall thickness of firetube in an area absorbingheat would be required to carry 500 psi if the tube isseamless SA-192, 4 in. in diameter and 15 ft long?Given

Do p 4 in.L p 15 ft p 180 in.P p 500 psi

Find: wall thickness of tube

Use: PFT-12, PFT-50, and PFT-51

Solve: Per PFT-51.1.2(a), determine if Do /t is greaterthan 10.

Calculate Do /t ≥ 10

where

Do p 4 in. (given)Do /t p 4/0.125 p 32

t p 0.125 in. (assumption)

Since Do /t is greater than 10, follow the procedure out-lined in PFT-51.1.2(a).Step 1: Calculate L /Do

where

Do p 4 in. (given)L p 15 ft (given)

L /Do p 180/4p 45

Calculate Do /t

where



Step 2: Enter Fig. G of Section II, Part D, forL /Do p 45

Step 3: Move horizontally to the line for Do /t p 32.From this point of the intersection, move verti-cally downward to get Factor A.

Factor A p 0.0013



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2010 SECTION I

Step 4: Enter Table 1A of Section II, Part D, forSA-192 ≤ 700°F per PFT-50 and PG-27.4, Note2. Enter Fig. CS-1 of Section II, Part D, andfind intersection of 0.0013 and 700°F.

Step 5: Move horizontally to the right to find Factor B.

Factor B p 7,000

Step 6: Calculate MAWP using the followingequation:

Pa p4B

3(Do /t)

where


Do p 4 in. (given)t p 0.125 in. (assumption)

Pa p4(7,000)

3(4 /0.125)

Pa p 292 psi

Step 7: Since Pa is less than actual P, select a largert and repeat the design procedure. Therefore,assume t p 0.20 in.

Per PFT-51.1.2(a), determine if Do /t is greaterthan 10.

Calculate Do /t ≥ 10

where



Since Do /t is greater than 10, follow the procedure out-lined in PFT-51.1.2(a).Step 1: Calculate L /Do

where

Do p 4 in. (given)L p 15 ft (given)

L /Do p 180/4p 45

Calculate Do /t

where

Do p 4 in. (given)Do /t p 4/0.20

p 20t p 0.20 in. (assumption)

Step 2: Enter Fig. G for L /Do p 45Step 3: Move horizontally to the line for Do /t p 20.

257

Factor A p 0.0028

Step 4: Enter Table 1A of Section II, Part D, forSA-192 ≤ 700°F per PFT-50 and PG-27.4, Note2. Enter Fig. CS-1 of Section II, Part D, andfind the intersection of 0.0028 and 700°F.

Step 5: Move horizontally to the right to find Factor B.

Factor B p 8,000

Step 6: Calculate MAWP using the followingequation:

P p4B

3 (Do /t)

where


Do p 4 in. (given)t p 0.20 in. (assumption)

Pa p4(8,000)3(4 /0.20)

Pa p 533 psi

Step 7: Since Pa is greater than P, the required thick-ness equals 0.25 in.

t p 0.20 in.

GUIDANCE FOR THE USE OF U.S.CUSTOMARY AND SI UNITS IN THE

ASME BOILER AND PRESSUREVESSEL CODE

A-391 USE OF UNITS IN EQUATIONS

The equations in this Nonmandatory Appendix are suit-able for use with either the U.S. Customary or the SIunits provided in Mandatory Appendix II, or with the unitsprovided in the nomenclature associated with that equation.It is the responsibility of the individual and organizationperforming the calculations to ensure that appropriate unitsare used. Either U.S. Customary or SI units may be usedas a consistent set. When necessary to convert from onesystem of units to another, the units shall be converted toat least three significant figures for use in calculations andother aspects of construction.

A-392 GUIDELINES USED TO DEVELOP SIEQUIVALENTS

The following guidelines were used to develop SI equiv-alents:

(10)



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2010 SECTION I

(a) SI units are placed in parentheses after the U.S.Customary units in the text.

(b) In general, separate SI tables are provided if interpo-lation is expected. The table designation (e.g., table num-ber) is the same for both the U.S. Customary and SI tables,with the addition of suffix “M” to the designator for theSI table, if a separate table is provided. In the text, refer-ences to a table use only the primary table number (i.e.,without the “M”). For some small tables, where interpola-tion is not required, SI units are placed in parentheses afterthe U.S. Customary unit.

(c) Separate SI versions of graphical information(charts) are provided, except that if both axes are dimen-sionless, a single figure (chart) is used.

(d) In most cases, conversions of units in the text weredone using hard SI conversion practices, with some softconversions on a case-by-case basis, as appropriate. Thiswas implemented by rounding the SI values to the numberof significant figures of implied precision in the existingU.S. Customary units. For example, 3,000 psi has animplied precision of one significant figure. Therefore, theconversion to SI units would typically be to 20 000 kPa.This is a difference of about 3% from the “exact” or softconversion of 20 684.27 kPa. However, the precision ofthe conversion was determined by the Committee on acase-by-case basis. More significant digits were includedin the SI equivalent if there was any question. The valuesof allowable stress in Section II, Part D generally includethree significant figures.

(e) Minimum thickness and radius values that areexpressed in fractions of an inch were generally convertedaccording to the following table:

ProposedFraction, in. SI Conversion, mm Difference, %

1⁄32 0.8 −0.83⁄64 1.2 −0.81⁄16 1.5 5.53⁄32 2.5 −5.01⁄8 3 5.55⁄32 4 −0.83⁄16 5 −5.07⁄32 5.5 1.01⁄4 6 5.55⁄16 8 −0.83⁄8 10 −5.07⁄16 11 1.01⁄2 13 −2.49⁄16 14 2.05⁄8 16 −0.8

11⁄16 17 2.63⁄4 19 0.37⁄8 22 1.01 25 1.6

(f) For nominal sizes that are in even increments ofinches, even multiples of 25 mm were generally used.

258

Intermediate values were interpolated rather than con-verting and rounding to the nearest mm. See examples inthe following table: [Note that this table does not apply tonominal pipe sizes (NPS), which are covered below.]

Size, in. Size, mm

1 2511⁄8 2911⁄4 3211⁄2 382 50

21⁄4 5721⁄2 643 75

31⁄2 894 100

41⁄2 1145 1256 1508 20012 30018 45020 50024 60036 90040 1 00054 1 35060 1 50072 1 800

Size or Length, ft Size or Length, m

3 15 1.5

200 60

(g) For nominal pipe sizes, the following relationshipswere used:

U.S. U.S.Customary Customary

Practice SI Practice Practice SI Practice

NPS 1⁄8 DN 6 NPS 20 DN 500NPS 1⁄4 DN 8 NPS 22 DN 550NPS 3⁄8 DN 10 NPS 24 DN 600NPS 1⁄2 DN 15 NPS 26 DN 650NPS 3⁄4 DN 20 NPS 28 DN 700NPS 1 DN 25 NPS 30 DN 750NPS 11⁄4 DN 32 NPS 32 DN 800NPS 11⁄2 DN 40 NPS 34 DN 850NPS 2 DN 50 NPS 36 DN 900NPS 21⁄2 DN 65 NPS 38 DN 950NPS 3 DN 80 NPS 40 DN 1000NPS 31⁄2 DN 90 NPS 42 DN 1050NPS 4 DN 100 NPS 44 DN 1100NPS 5 DN 125 NPS 46 DN 1150NPS 6 DN 150 NPS 48 DN 1200NPS 8 DN 200 NPS 50 DN 1250NPS 10 DN 250 NPS 52 DN 1300NPS 12 DN 300 NPS 54 DN 1350NPS 14 DN 350 NPS 56 DN 1400NPS 16 DN 400 NPS 58 DN 1450NPS 18 DN 450 NPS 60 DN 1500



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2010 SECTION I

(h) Areas in square inches (in.2) were converted tosquare mm (mm2) and areas in square feet (ft2) were con-verted to square meters (m2). See examples in the follow-ing table:

Area (U.S. Customary) Area (SI)

1 in.2 650 mm2

6 in.2 4 000 mm2

10 in.2 6 500 mm2

5 ft2 0.5 m2

(i) Volumes in cubic inches (in.3) were converted tocubic mm (mm3) and volumes in cubic feet (ft3) wereconverted to cubic meters (m3). See examples in the follow-ing table:

Volume (U.S. Customary) Volume (SI)

1 in.3 16 000 mm3

6 in.3 100 000 mm3

10 in.3 160 000 mm3

5 ft3 0.14 m3

(j) Although the pressure should always be in MPa forcalculations, there are cases where other units are used inthe text. For example, kPa is used for small pressures.Also, rounding was to one significant figure (two at themost) in most cases. See examples in the following table:(Note that 14.7 psi converts to 101 kPa, while 15 psiconverts to 100 kPa. While this may seem at first glanceto be an anomaly, it is consistent with the rounding phi-losophy.)

Pressure (U.S. Customary) Pressure (SI)

0.5 psi 3 kPa2 psi 15 kPa3 psi 20 kPa10 psi 70 kPa

14.7 psi 101 kPa15 psi 100 kPa30 psi 200 kPa50 psi 350 kPa100 psi 700 kPa150 psi 1 MPa200 psi 1.5 MPa250 psi 1.7 MPa300 psi 2 MPa350 psi 2.5 MPa400 psi 3 MPa500 psi 3.5 MPa600 psi 4 MPa

1,200 psi 8 MPa1,500 psi 10 MPa

259

(k) Material properties that are expressed in psi or ksi(e.g., allowable stress, yield and tensile strength, elasticmodulus) were generally converted to MPa to three sig-nificant figures. See example in the following table:

Strength (U.S. Customary) Strength (SI)

95,000 psi 655 MPa

(l) In most cases, temperatures (e.g., for PWHT) wererounded to the nearest 5°C. Depending on the impliedprecision of the temperature, some were rounded to thenearest 1°C or 10°C or even 25°C. Temperatures colderthan 0°F (negative values) were generally rounded to thenearest 1°C. The examples in the table below were createdby rounding to the nearest 5°C, with one exception

Temperature, °F Temperature, °C

70 20100 38120 50150 65200 95250 120300 150350 175400 205450 230500 260550 290600 315650 345700 370750 400800 425850 455900 480925 495950 510

1,000 5401,050 5651,100 5951,150 6201,200 6501,250 6751,800 9801,900 1 0402,000 1 0952,050 1 120

A-393 SOFT CONVERSION FACTORS

The following table of “soft” conversion factors is pro-vided for convenience. Multiply the U.S. Customary valueby the factor given to obtain the SI value. Similarly, dividethe SI value by the factor given to obtain the U.S. Custom-ary value. In most cases it is appropriate to round theanswer to three significant figures.



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2010 SECTION I

U.S.Customary SI Factor Notes

in. mm 25.4 . . .ft m 0.3048 . . .in.2 mm2 645.16 . . .ft2 m2 0.09290304 . . .in.3 mm3 16,387.064 . . .ft3 m3 0.02831685 . . .U.S. gal m3 0.003785412 . . .U.S. gal liters 3.785412 . . .psi MPa (N/mm2) 0.0068948 Used exclusively in

equationspsi kPa 6.894757 Used only in text

and for nameplatepsi bar 0.06894757 . . .ft-lb J 1.355818 . . .°F °C 5⁄9 � (°F − 32) Not for temperature

difference°F °C 5⁄9 For temperature

differences onlyR K 5⁄9 Absolute temperaturelbm kg 0.4535924 . . .lbf N 4.448222 . . .in.-lb N·mm 112.98484 Use exclusively in

equationsft-lb N·m 1.3558181 Use only in textksi�in. MPa�m 1.0988434 . . .Btu/hr W 0.2930711 Use for boiler rating

and heat transferlb/ft3 kg/m3 16.018463 . . .

260



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2010 SECTION I

NONMANDATORY APPENDIX BPOSITIVE MATERIAL IDENTIFICATION PRACTICE

B-1 INTRODUCTION

As part of his material control system, a Manufacturermay determine that a situation warrants positive materialidentification for a specific material or item. This mayinclude material used by the Manufacturer for pressureretaining boiler parts and their associated support materialsand may also include components covered by PG-11 orby ASME standards listed in Table A-360. This Nonman-datory Appendix is provided as a guide for use by theManufacturer in developing a Positive Material Identifica-tion Practice (PMIP) that may be applied to address thematerial or item of concern.

B-2 DEFINITIONS

Some commonly used terms relating to this practice aredefined below.

calibration check: a test carried out on a known standardalloy to verify the performance of the instrument.

certified mill or material test report (CMTR): a docu-ment that permits each component to be identifiedaccording to the original heat of material from which itwas produced.

inspection lot: with the exception of bolting, an inspec-tion lot is a group of components from the same heatnumber or lot from which a sample is drawn. For bolting,a lot is a group of similar components in terms of alloytype and size.

100% positive material identification: each individualcomponent and weld is tested.

OES: optical emission spectroscopy.positive material identification (PMI): a procedure used

to ensure that specified metallic alloy materials are(a) properly identified as to alloy type(b) identified in accordance with the Manufacturer’s

written practice(c) installed as intended.representative sampling: PMI testing of a sample, which

consists of one or more pieces (components), selected atrandom from an inspection lot, that will be examined todetermine acceptability of the inspection lot.

XRF: x-ray fluorescence.

261

B-3 SCOPE

This PMIP may be applied to metals during the supply,fabrication, and erection of these materials. This practiceis not intended for PMI of material already in service,although many of the procedures and concepts are equallyapplicable.

This PMIP covers the procedures and methods to ensurethat the nominal chemical content of specific key elementsin metallic alloys is in accordance with purchase specifica-tions, and that such materials are properly analyzed andidentified to indicate the alloy.

The user is cautioned that this PMIP does not ensurethat the materials have been processed correctly and havethe appropriate mechanical properties for the intendedservice.

B-4 BASIS

The primary basis for this PMIP is the application ofportable X-ray fluorescence (XRF). The state-of-the-artwith these instruments is continually improving but XRFinstruments typically are incapable of quantitative mea-surements for elements with an atomic number lower than22 (titanium). In particular, the XRF method is incapableof measuring carbon (atomic number 6), which is a criticalelement in many of the alloys for which PMI is desired.When the measurement of carbon or other elements withan atomic number less than 22 is desired, the user mayalso apply optical emission spectrometers (OES). OESinstruments produce an electrical arc between the instru-ment and work piece so the examined area shall be selectedto minimize damage to critical surfaces.

This PMIP does not provide absolute confirmation ofall mandatory elements in the materials specification in thesame sense as the more sophisticated laboratory methodssuch as wet chemistry, optical emission spectroscopy,energy dispersive spectroscopy, combustion/infrared spec-troscopy, atomic absorption spectroscopy, etc. Neverthe-less, when coupled with other documentation such ascertified mill or material test report (CMTR), a Certificateof Compliance (COC), or material marking, this PMIP canestablish a high degree of confidence that the materialmatches what was intended.



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2010 SECTION I

TABLE B-1IDENTIFICATION ELEMENTS

Materials Identification Elements Materials Identification Elements

Carbon steel C [Note (1)], Si [Note (1)], Alloy 20Cb-3 C [Note (1)], Cr, Ni, Mo, Cb, CuMo, Cu < 0.43, Ni < 0.43,Cr < 0.34, Mo < O.13,(V + Cb) < 0.07,(Cr + Mo) < 0.32,(Cu + Ni + Cr + Mo) < 1.00

C-1⁄2Mo Mo Brass, admiralty Sn1 Cr-1⁄2 Mo Cr, Mo Brass, naval Sn11⁄4 Cr-1⁄2 Mo Cr, Mo Brass, aluminum Zn, AI21⁄4 Cr-Mo Cr, Mo 90/10 Cu/Ni Cu, Ni5 Cr-1⁄2 Mo Cr, Mo 70/30 Cu/Ni Cu/Ni7 Cr-1⁄2 Mo Cr, Mo Alloy 400 Ni, Cu9 Cr-l Mo Cr, Mo AL-6XN Cr, Ni, Mo9Cr-1Mo-0.2V Cr, Mo, V Titanium Grades 1 and 2 Ti12 Cr (Type 405/410SS) C [Note (1)], Cr Grade 12 Ti Ti, Mo [Note (1)], Ni [Note (1)]12 Cr (Type 410) Cr Grade 16 Ti Ti, Pd [Note (1)]17 Cr (Type 430) Cr Alloy 182 Ni, Cr25 Cr (Type 446) Cr Alloy 600 Ni, Cr304 Cr, Ni Alloy 625 Ni, Cr, Mo, Cb, Ti304L C [Note (1)], Cr, Ni Alloy 800 Ni, Cr, AI, Ti304H C [Note (1)], Cr, Ni Alloy 825 Ni, Cr, Mo, Cu, Ti309L C [Note (1)], Cr, Ni AISI 4140 C [Note (1)], Cr309CbL C [Note (1)], Cr, Ni, Cb AISI 4340 C [Note (1)], Cr, Ni310 Cr, Ni Alloy 2205 Cr, Ni, Mo316/317 Cr, Ni, Mo Alloy 2507 Cr, Ni, Mo316L/317L C [Note (1)], Cr, Ni, Mo 3.5Ni, 5Ni, and 9Ni Ni321 Cr, Ni, Ti Hastelloy C276 Ni, Cr, Mo, W347 Cr, Ni, Cb . . . . . .

GENERAL NOTE: Percentages shall be within the limits specified in the appropriate standards/specifications.

NOTE:(1) See B-7 for options related to these minor alloying elements.

B-5 MATERIALS

The materials that are covered in this PMIP include lowalloy steels, high alloy steels, and nickel based alloys forwhich direct elemental measurement of key elements ispossible.

Carbon steel may be confirmed using XRF by directmeasurement of manganese plus direct measurement ofcertain residual elements with confirmed low levels consist-ent with carbon steel. Alternatively, OES may be appliedto carbon steels in order to directly measure elements suchas carbon and silicon.

B-6 WRITTEN PRACTICE

The PMI program shall be covered in a written practice.The written practice shall define the method of testing,acceptance criteria, sampling plan, documentation require-ments, material identification requirements, instrument tobe used, frequency of instrument calibration and instrumentcalibration checks, personnel qualification requirements,and control of rejected material.

262

B-7 METHOD

The practice shall define the type of test to be performed;XRF or OES. When using XRF, the practice shall alsodefine whether analysis mode or alloy matching mode shallbe used.

When identification of minor alloying elements (e.g.,low carbon in Type 304L SS or Type 410 SS, minoralloying elements in various grades of titanium) is required,the methods for testing and the acceptance criteria shallbe identified in the written practice.

Suitable methods for identifying minor elementsinclude: specialized laboratory instrumentation, suitableoptical emission spectroscopy (field portable or labora-tory), traceable mill certificates, or a combination of trace-able mill certificates and chemical analysis using lowermeasurement sensitivity.

B-8 ACCEPTANCE CRITERIAB-8.1 The minimum elements to be tested for each

alloy type are as listed in Table B-1. For alloys not includedin Table B-1, the user shall identify elements to be tested.



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2010 SECTION I

B-8.2 When examining with XRF in an analysis mode,the measured value of alloying elements shall be within10% of the specified level or range in the applicable materi-als standards. For example, for 5Cr, where the allowablerange is 4% to 6%, the measured value shall fall withinthe range 3.6% to 6.6%.

B-8.3 When examining with XRF in an alloy identifi-cation or alloy matching mode, the instrument shall confirmthat alloys comply with the specified standard. The instru-ment shall provide quantitative, recordable, elemental com-position results for positive identification of the alloyelements present.

B-8.4 If PMI test results indicate that the componentis not the specified material, the item shall be rejected.

B-8.4.1 When test results using XRF or OES falloutside the acceptable range, a quantitative analysis may beperformed by a laboratory test. If no method is referenced inthe applicable materials standard, an appropriate methodof chemical analysis shall be used. Results of this analysisshall govern.

B-8.4.2 Material rejected by PMI shall be markedand controlled in accordance with the Manufacturer’s writ-ten practice.

B-9 SAMPLING PLAN

Whether 100% PMI or representative sampling is to beapplied shall be established in the written practice. Whenrepresentative sampling is identified in the written practice,the written practice shall also identify an extension planto be used when some material in an inspection lot isrejected.

B-9.1 The following metallic-alloy-material itemsshould be considered as candidates for Positive MaterialIdentification (PMI):

(a) weld caps and root passes for all pressure-con-taining welds

(b) all pressure-containing tubing and piping compo-nents (includes thermowells, instrument manifolds, etc.)

(c) plate material used as pressure-containing compo-nents

(d) external valve components (body, flanges, bonnet,plugs and vents, and associated welds)

(e) expansion joints and bellows in pressure-containingservice

(f) air-cooled heat exchanger tubes (air fin tubes)(g) materials with no alloy type identification (i.e., per-

manent markings)(h) internal metallic lining/cladding and weld overlay

used for protection against corrosive environments(i) load bearing attachments

263

(j) heat exchanger and boiler internal supports (tubehangers, tube supports, and tubesheets)

(k) all fasteners greater than 2 in. in diameter(l) ring joint flange and clamp-type connector flange

gasketsIf any piece from the representative sample is found to

be unacceptable, the extension plan in the written practiceshall be followed.

B-9.2 Exempt. The following items are typically con-sidered as exempt:

(a) alloy components, where the alloy is installed forproduct purity consideration only. The Manufacturer mayspecify PMI requirements if special alloy requirements areneeded for environmental concerns.

(b) internal instruments parts, including orifice plates(c) non-pressure-containing welds(d) stainless steel instrument tubing and copper tubing

with an outside diameter of 3⁄4 in. (19 mm) and less, whenproperly identified by paint stencil (exchanger tubing isnot included in this exemption)

(e) all gaskets, except as required by B-9.1(f) parts that are internal to pressure parts and are not

pressure containing

B-10 DOCUMENTATION

Records of PMI results shall include the following as aminimum:

B-10.1 For fabricated or assembled equipment, theserecords shall include an itemized list of all componentsand welds tested.

B-10.2 Tabulation of tested items shall be keyed todrawings through the use of reference numbers.

B-10.3 Positively identified materials shall be traceableto any required material documentation, such as mill testreports.

B-10.4 The Manufacturer’s records of alloy verificationshall be available for review upon completion of theequipment.

B-11 IDENTIFICATION

Each component (or weld) tested shall be identified afterPMI inspection and acceptance. This identification shallbe in addition to markings required by this Section or bythe standards listed in Table A-360.

Each component or weld analyzed and accepted shallbe identified in accordance with the Manufacturer’s writtenpractice. This identification may include color coding, lowstress stamping, or documentation showing the PMI loca-tion and test results.

When material is cut after PMI testing and identification,each piece of material shall be identified in accordancewith the Manufacturer’s written practice.



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2010 SECTION I

INDEX

Access door, PWT-14, PWT-15, PFT-40, PFT-42Access openings, PG-44, PFT-42Accumulation test of safety valve capacity, A-46Adamson furnace, PFT-16Allowable working pressure (see Working pressure)ANSI Standard steel pipe flanges and fittings, PG-42Appliances and fittings, PG-42, PG-58 to PG-60Application of Code, PreambleApproval of new materials under Code, A-75 to A-80

unidentified materials, PG-10Assembly, field, PG-107Attachment of piping to boiler outlets, PG-59, PFT-49Automatic shutoff valves on water gages, PG-60, A-18

Backing rings for welded pipe joints, PW-41Bars (see Crown bars, Steel bars, etc.)Beading tube ends, PFT-12Bending stresses on welding joints, PW-9Blowdown for safety valves, PG-72Blowoff piping and fittings, PG-42, PG-59Boiler external piping, Figs. PG-58.3.1 & PG-58.3.2Boiler parts, permissible specifications for, PG-9Boilers, scope of Section I, PreambleBox header sheets, welded joints between, PWT-12

Fig. PWT-12.1, Fig. PWT-12.2Braced and stayed surfaces, PG-46 to PG-49, PFT-22 to

PFT-32Brackets, fusion welded, PG-55, PFT-46Brass and copper pipe, PG-9

screwed or flanged type fittings or valves, PG-8, PG-42Brown furnaces, PFT-18Btu of various, A-17Bushing, boiler, for pipes, PG-59, Fig. PG-59.1

Cast, iron, flanged and threaded fittings, PG-42for boiler and superheater connections, PG-8

Castings, quality factors, for steel, PG-25for pressure parts, PG-8

Castings, permissible specifications for, PG-8Check valves in feedpipe, PG-58, Figs. PG-58.3.1 &

PG-58.3.2Circular furnaces, PFT-15Circumferential joint (see Joints)Cleanout door in setting, PWT-15, PFT-42Cocks (see Blowoff piping & fittings)

264

Code application, stamp (see Stamp; Stamping)Coil-type hot water boilers, PG-2Combustion chamber, materials for, PG-6

sling stays, PFT-13.2tubesheets of, PFT-13

Cones, truncated, PFT-23.4Connections, area of, with two or more safety valves, PG-71

welded, for nozzles, PG-42, PG-43expanded, for openings, PG-39pipe, welded, PW-41studded, for openings, PG-39threaded, for openings, PG-39to safety valves, PG-71to steam gages, PG-60to test gages, PG-60water column, PG-60welded, for openings, PG-39, PW-15, PW-16

Copper and brass pipe, PG-9screwed or flanged-type fittings or valves, PG-8, PG-42tubes, working pressure of, PFT-12

Corner radius of unstayed dished head, PG-29Corrugated furnaces, PFT-18, PFT-19Cover plates, material, PG-44Cross-pipe materials, PG-5Crown bars and girder stays, PFT-30Curved stayed surface, subject to internal pressure, PFT-23Cutting of plates, PG-76, PW-29Cylindrical and noncylindrical pressure parts, fusion welding,

Part PW

Data Report Forms, PG-112, A-350 to A-357Master Data Report Form, PG-113

Defects, in welded joints, repairing of, PW-40Definitions of fusion welding processes, PW-1Deformation test, hydrostatic, PG-18, PG-100, A-22Design rules, PG-16Diagonal stays, stresses in, PFT-32Discharge pipe from safety valves, PG-71, PFT-44Dished heads, PG-29

convex to pressure, PG-29corner radius, PG-29flanged-in manhole, PG-29, PG-34depth of flange, PG-34radius, PG-29staying, PG-30



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2010 SECTION I

thickness, PG-29Distortion of welded drums or shells, PG-80Dome plates, thickness, PFT-9Domes, PFT-45

seamless, construction, PG-7, PFT-45Door frame rings, holes, welded latches, PWT-14

material, PFT-5size, PWT-15, PFT-42

Drains, PG-59from economizers, waterwalls, or water screens, PG-59from superheater, PG-59

Drilling, tube holes, PG-79, PFT-12Drum forgings, material, PG-7

with integral heads, PG-7Drums, boiler, pipe or tubing for, PG-9

computations of openings in, A-65 to A-69distortion, PG-80fusion welding, Part PW

inspection, PW-46 to PW-53material, PW-5

longitudinal joints (see Joints)mud drum, material, PWT-5seamless construction, PG-7

Ductile iron, flanged fittings, PG-42

Efficiency, PG-27, PG-52, PG-53Electric boilers, PG-16, PG-58, PG-67, PG-70, PG-105,

PG-106, PG-112, PMB-2, PMB-10, PMB-17, Part PEB,Data Report Form P-2A, A-351

Existing installations, repairs to, A-64Explosion doors in setting, PWT-14

Facing dimensions for steel flanges, PG-42Factors of safety (see Safety factors)Feedpipe, fittings and valves, PG-58, PG-59Feedpumps, PG-61Feedwater heaters, optional requirements when located within

scope of Section I rules, Part PFHFeedwater heaters, provisions to prevent overpressure, PG-58Field assembly, PG-107Firebrick casing for blowoff pipe, PG-59Fired steam boiler, definition, PreambleFiring doors, PWT-14, PWT-15, PFT-42Fittings, and appliances, application requirements for

boiler proper, PG-59flanged connections, PG-42material of, between boiler and valves, PG-58

Flanges, blind, thickness of, PG-31cast iron or steel, PG-42material of, PG-58pipe, PG-42steel, facing dimensions of, PG-42

Flat heads, PG-31Flat plate in corner joints, inspection and repair of, PG-93

265

Flat surfaces, on dished head, PG-30to be stayed, PG-46, PFT-24 to PFT-26

Flues, circular, pressure on, PFT-51Forgings, permissible specifications for, PG-7Fox furnace, PFT-18Furnaces, Adamson type, PFT-16

Brown, PFT-18Code stamping, PG-106 to PG-111combined plain and corrugated type, PFT-19corrugated, PFT-18Fox, PFT-18Leeds suspension bulb, PFT-18material for, PG-6maximum allowable working pressure, PFT-14 to PFT-19Morison, PFT-18plain circular, PFT-15Purves, PFT-18Ring reinforced type, PFT-17staying for vertical firetube boiler, PFT-23vertical boilers, PFT-23

Fusible plugs, A-19 to A-21tubes for, PWT-9typical forms of, Fig. A-10

Fusion welding (see Welding)

Gage cocks, PVG-10Gage glass, body and connector material, PG-12Gages (see Steam; Test; Water glasses, etc.)Gaskets, manhole, PG-44Girder stays and crown bars, PFT-30

Handhole, PFT-43in shell or unstayed head, design, PG-44

Handhole plates, material of, PG-44Hangers to support boilers, PG-55, PFT-46Headers, box type, PWT-12Heads, area to be stayed, PWT-13, PFT-24, PFT-25

dished, PG-30flat, PG-31segments of area to be stayed, PFT-25staying, PFT-24, PFT-25with manholes, PFT-27

Heating surface, estimating steaming capacity, A-44Hemispherical dished heads, PG-29High-temperature water boilers, PG-2, PG-61Holes, for screw stays, PG-82

for tubes, PG-79, PFT-12spacing, PG-52, PG-53tube (see Tube holes)

Hydrostatic pressure test, PG-99fusion welded boilers, PW-54proof testing, A-22

Identification of plates, PG-77



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2010 SECTION I

Inspection, PG-90and repair of flat plate in corner joints, PG-93at place of manufacture, PG-90authority use of symbol, PG-105of welded drums during construction, PG-90openings, PG-44, PFT-43

Insulation of blowoff pipe, PG-59Internal collecting pipe, PG-71Inward-opening firing doors, PWT-14Iron wrought, for waterleg and doorframe rings, PFT-5Iron, cast (see Cast iron)

Joints, buttwelded, definition, PW-1electric resistance buttwelded, PW-27fusion welded, PW-27

postweld heat treatment, PW-39preheating, PW-38, A-100

longitudinal, of plain circular furnaces, PFT-14pipe radiography, PW-11, PW-14

welded, design of, PW-9welded, between staybolted box header sheets, PWT-12welded, reinforcement, PW-35welded, test requirements for, PW-46 to PW-54

Latches, firing door, PWT-14Leeds suspension bulb furnace, PFT-18Ligaments, PG-27, PG-52, PG-53

efficiency, PG-27, PG-52, PG-53diagrams, Figs. PG-52.1 & PG-52.6

Limits of Code pipingdrum-type boiler, Fig. PG-58.3.1forced flow steam generator with no fixed steam and

waterline, Fig. PG-58.3.2Limits of compensation for openings, PG-36Liquid penetrant examination and acceptance standards, PG-25

methods for, A-270Load, on structural attachments to tubes, PW-43, A-71 to A-74Locomotive-type boiler, dome diameter, PFT-45

waterleg and doorframe rings, PFT-5Longitudinal joints (see Joints)Lugs, support and attachment, PG-55

to support HRT boilers, PFT-46

Machining plates for welding, PW-29Magnetic particle examination and acceptance standards,

PG-25methods for, A-260

Malleable iron, screwed fittings, PG-42Manholes, PG-44, PFT-43

covers, forming of, materials, PG-44elliptical, size, PG-44gaskets, bearing surface, PG-44in a shell or unstayed head, sizes and design, PG-44

266

in dished heads, PG-34in firetube boilers, PFT-43ring, material of, PG-11

Manufacturers’ Data Report, PG-112, A-350 to A-356Manufacturers’ stamping of boiler, PG-106Materials, acceptable for fusion welding, PW-5

approval of new, PG-5, A-75 to A-80door frames and waterlegs, PFT-5for welded piping, PW-5selection, PG-5specifications for, PG-6 to PG-9stays and staybolts, PG-15stress values, maximum allowable

ferrous, A-24, Table PG-23.1nonferrous, A-256, Table PG-23.2, A-26, Table PG-23.3

under tolerance, PG-16unidentified, PG-10

Maximum allowable working pressure (see Working pressure)Metric conversion tables, follows A-356Miniature boilers, Part PMBMorison furnace, PFT-18Mud drums (see Drums)Muffler on safety valve, PG-71

New materials, approval of, PG-5Nipple or pipe connections, threaded joints for, PG-39Nondestructive examinations, PG-25, PW-11, Table PW-11Nondestructive testing personnel qualification and certification,

PG-25, PW-51, PW-52Nonferrous tubes and pipes, specifications for, PG-9Nonpressure parts, welded, PW-39, PW-54Numbers, serial, manufacturer’s, PG-106

Ogee flanged construction, PFT-5Openings and reinforcements, in shells, headers and heads,

PG-32between boiler and safety valve, PG-71, PFT-44inspection, handhole or washout, in shell or unstayed head,

PG-44in wrapper sheets, PFT-41in formed heads, PG-34reinforcement computation examples, A-65 to A-70

Operator qualifications for welding, PW-28Organic fluid vaporizer generators, Part PVG

Partial Data Reports, PG-112Parts, miscellaneous pressure, PG-11

nonpressure, welded, PW-39Pipe connections, welded, PW-15Pipe nozzle in shell, computation of, A-68Pipes, attachment to boiler, PG-59, PW-35, PFT-48, PFT-49

blowoff (see Blowoff piping)collecting, internal, PG-71



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2010 SECTION I

for watertube boilers, PWT-9nonferrous, PG-9or tubes, thickness, PG-27surface blowoff, PG-59threads, number, PG-39, Table PG-39undertolerance, PG-16water column, PG-60

Piping, and connections included with boiler, PG-11, PG-58,Figs. PG-58.3.1 & PG-58.3.2

authority, use of symbol, PG-108blowoff (see Blowoff piping)connected to boiler outlets, PG-58, PG-59feed, PG-59welded qualification of process and operators for, PW-28

Plate, thickness of shell or dome after forming, PFT-9undertolerance, PG-16

Plates, cutting, PG-76for stayed flat surfaces, PG-46identification, PG-77manhole, material, PG-44preparation for welding, PW-29steel (see Steel plates)steel, tensile strength of, PG-23, Table PG-23.1thickness, outside limits in specifications, PG-5

minimum, PG-16, PG-27, PG-29, PG-34, PFT-9welded, cutting, PW-29

Plugs, fusible, A-19 to A-21Postweld heat treatment, PW-39, Table PW-39PreamblePreheating, PW-38, A-100Pressure, maximum allowable working (see Working pressure;

also Shell, Tubes, etc.)Pressure parts, included with boiler, PG-11, PG-58,

Figs. PG-58.3.1 & PG-58.3.2postweld heat treatment, PW-39

Pressure test, hydrostatic (see Hydrostatic pressure test)Proof tests to establish maximum allowable working pressure,

A-22, A-23Pumps or injectors for feeding boiler, PG-61Purves furnace, PFT-18

Qualification of welding procedures and operators, PW-28Quality control system, PG-105, A-300Quality factors for steel castings, PG-25

Radiographic examinations, PG-25, PW-11, Table PW-11acceptance standards for castings, PG-25acceptance standards for welds (when mandatory), PW-51of welded butt joints, PW-11, Table PW-11

Referenced standards, PG-3, A-360Reheaters, safety valves, PG-68Reinforced openings, for pipe connections, PW-15

in dished heads, PG-29in unstayed flat heads, PG-31

267

nozzle, PW-15Reinforcement of welded joints, limits of, PG-33Reinforcements, of welded joints, PW-35Relieving, stress, in fusion welded joints (see Postweld heat

treatment)Repairing defects in welded joints, PW-40Repairs, existing installations, A-64Report, Manufacturers’ Data, PG-112, PG-113Reservoirs on steam mains, PG-59Resistance, electric, butt welded joints, PW-27Ring joint flanges, facing dimensions of, PG-42Rings, backing, for welded pipe joints, PW-41

waterleg and door frame, PFT-5Riveted boilers, A-30Rods for stays, support of, PFT-28Rolling and expanding tube, PWT-11, PFT-12

Safety valves, PG-67 to PG-73, PG-105, PG-110, PVG-12,A-12 to A-17, A-44 to A-48

additional, existing installations, A-48capacity, examples of checking, A-12 to A-17

methods of checking, PG-70casing, PG-69connections, PG-67.5, PG-71, PFT-44constructions, PG-67, PG-68design requirements, PG-73discharge capacity, PG-67, PG-68, PG-70, PVG-12discharge pipe, PG-71duplex, PG-71economizer, PG-67existing installations, A-44, A-45forced circulation boilers, PG-72inspection of mfr. and assembly, PG-73markings required, PG-110marking to constitute guarantee, PG-69material selections, PG-73maximum rise in pressure, PG-67mechanical requirements, PG-73method of checking safety valve capacity, A-12 to A-17minimum requirements for, PG-67mounting, PG-71muffler on, PG-71organic fluid vapor generators, PVG-1outdoor shield, PG-71popping point tolerance, PG-72power actuated, PG-67required on boiler, PG-67seats, PG-67, PG-73setting, PG-67, PG-72springs, PG-72, PG-73stamping, PG-105, PG-110superheater, PG-68test accumulation, PG-70

existing installations, A-46



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2010 SECTION I

testing, PG-69, PG-73twin, PG-71

Scope of Code, Preamble, PG-1Screwed fittings or valves (see Fittings)Screwed stays, supporting of, PFT-28Seamless drums or shells , PG-7

(see Tubes)Selection of materials, PG-5Serial number, PG-106Setting boilers, outside suspension, PFT-46Setting safety valves, PG-67Shell or drum, allowable pressure on, PG-27

fusion welding, Part PWlongitudinal joints of, PFT-10material for welded shells, PW-5openings in, computation of, A-65 to A-70plate, thickness, PFT-9seamless construction, PG-7

Shutoff valves, automatic on water gages, PG-60on water column connection, PG-60

Sling stays, PFT-13, PFT-30Socket type joint connections of pipe, PW-41Sootblower connection to superheater outlet, PG-68Spacing between stays, PFT-27Specifications for materials, PG-5 to PG-13Stamp, Code symbol, PG-105, Fig. PG-105.1 to Fig. PG-105.4

boilers, PG-106field assembled boilers, PG-108

Stamping, location, PG-111pressure piping, PG-109safety valves, PG-110shell plates, furnace sheets and heads, PG-77, PG-106transferring markings, PG-77, PG-106

Staybolts, adjacent to edges of surface, PG-48, Fig. A-8adjacent to furnace door, PFT-27, Fig. A-8allowable stress, PFT-28detailed and proportions, PG-47, PG-49, PFT-27, Fig. A-8flexible, with welded cover cap, PFT-29holes for, PG-82material, PG-13pitch, PG-46, PFT-27stresses, PFT-23, PFT-28welded, PW-19

Stayed surfaces, PG-46 to PG-49, PW-19, PWT-13, PFT-22 toPFT-32, A-8, Fig. A-8

curved surfaces, PFT-23flat surfaces, PG-46

Stayed wrapper sheet, PFT-23, Fig. PFT-23.1Staying, dished heads, PG-30

furnaces, PFT-23segments of heads, PFT-25

with manhole openings, PFT-27, Fig. A-8segments of tube sheets, PFT-25

Stay rods, ends riveted over, PFT-28

268

Stay tubes, PFT-31Stays and staybolts, PG-13, PG-46 to PG-49, Fig. PG-46.2,

PW-19, PFT-22 to PFT-32, PW-19, A-8, A-10,Table A-4, Fig. A-8

allowable stress on, PFT-28area to be supported, PFT-26diagonal stays, PFT-32ends of, PG-46, PF-47, PW-19, PFT-22 to PFT-32fusion welding of, PW-19girder, PFT-30length between supports, PFT-28material of, PG-13screwed, diameter, PG-49, PFT-28, A-8

supporting, PFT-28sling, PFT-13stress on, PFT-28stresses, in diagonal stays, PFT-32through-stays, PG-46, PFT-24, PFT-28upset for threading, PG-47welded, cross-sectional area, PW-19

Stay tubes, area to be supported by, PFT-31Steam cleaners, PG-2Steam gages, PG-60

and connections, PG-60dial, graduation of, PG-60test connection, PG-60

Steam generating capacity, examples of checking, A-12 toA-17

Steam mains, PG-59Steam outlets, PG-59Steel, cast, fittings or valves, PG-42

wrought or cast, for boiler and superheater parts, PG-9flange, PG-42for watertube boilers, PG-5

Steel bars for boiler parts, PG-13Steel fittings, flanged, PG-42

terminating flanges for, PG-42working pressure for, PG-42

Steel plate, tensile strength of, PG-23Steel plates, exposed to fire, PG-6Stock parts, cast, forged, or rolled, PG-11Stop valves (see Valves)Strength, of circumferential welded joints, PW-41

of structure that cannot be calculated, test, PG-100, A-22Stresses allowable in ferrous materials, PG-23, A-24,

Table PG-23.1in nonferrous materials, PG-23, A-25, Table PG-23.2, A-26,

Table PG-23.3Stress relieving of fusion welded joints (see Postweld heat

treatment)Structural attachments to tubes, computation of loading on,

PW-43, A-71 to A-74Structural reinforcement for heads, PG-30Studded connections, PG-39



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2010 SECTION I

connection in shell, computation of, A-67Superheater, drains, PG-59

material for, PG-9safety valve on, PG-68shutoff valve, PG-59tubes, welded, PW-41tubes and nipples, PWT-9, PWT-11, Fig. PWT-11

Surface blowoff, PG-59Suspension type of boiler setting, PFT-46

Tell tale holes, drilling, PG-47, PW-19, PFT-29Temperature of metal during hydrostatic test, PG-99Tension test of joint specimen, PW-53Test, hydrostatic, of fusion welded drums, PW-54

hydrostatic pressure (see Hydrostatic pressure test)nondestructive, of welded joints, PW-51, PW-52of safety valve capacity, PG-70

existing installations, A-44 to A-48of structure of which the strength cannot be calculated,

PG-100, A-22requirements for fusion-welded joints, PW-46 to PW-54

Test gage, connection, PG-60Test gages, PG-99, A-22Thickness of plates, undertolerance, PG-16Threaded connections, flanged in shell, computation of, A-66Threads, fitting into pipe or nipple, PG-59

pipe, number for boiler connection, Table PG-39Through-stays, PG-46, PFT-24Tin for fusible plugs, A-19Transfer of markings on plate, PG-77Truncated cones, pressure on, PFT-23.4Tube ends, expanding, PWT-11, Fig. PWT-11

firetube boiler, PFT-12flaring, PWT-11, Fig. PWT-11watertube boilers and superheaters, PWT-11, Fig. PWT-11

Tube holes, and ends, PG-79, PFT-12, PWT-11, Fig. PWT-11diagonal, in shell or drum, PG-52drilling or punching, PG-79in shell or drum, PG-52, PG-53pitch, PG-52, PG-53sharp edges, removed, PG-79

Tubes, and pipes, nonferrous, PG-27attachments, typical structural, PW-43, A-71 to A-74for firetube boilers, PFT-12stay, PFT-31structural attachments, load on, PW-28, PW-43, A-71 to

A-74, Figs. A-71 to A-74thickness, PG-27, PG-43, PWT-9, PWT-10undertolerance, PG-16welded connections of, PW-41working pressure, PG-27

Tubesheets, combustion chambers, PFT-13cylindrical, ligaments in, PG-52insertion of, in shell, PFT-11

269

thickness of, PFT-9unstayed, space allowed, PFT-25

Tube spacing, PG-52

Ultrasonic examinations, PW-11, Table PW-11acceptance standards for welds, PW-52of welded butt joints, PW-11, Table PW-11

Unfired steam boiler, classification, PreambleUnreinforced openings, dished heads, PG-29

in shell, computation of, A-65nozzles, PW-15, PW-16

Unreinforced welded joints, holes in, PW-14Unstayed circular furnaces, rules for, PFT-15Unstayed flat heads, reinforced openings in, PG-35

thickness, PG-31unreinforced openings in, PG-32

Unsymmetrical spacing of staybolts, PG-46.7

Valves, PG-58, PG-59automatic, on water gages, PG-60, A-18blowoff (see Blowoff valves)bodies or fittings, thickness, PG-42cast iron, PG-8drain (see Drains)flanges of, PG-42material, PG-11on steam outlet, PG-59on supply line, PG-59on water fronts, PG-60

on water column, PG-60safety (see Safety valves)

stop, PG-59Vertical firetube boilers, PG-43

Washout openings, PFT-43in shell or unstayed head, PG-44

Water column, and connection, PG-60design and material of, PG-60shutoff valves on, PG-60

Water fronts, valves on, PG-60.5Water gage glass, lowest visible part of, PG-60Water gages, automatic, A-18Water glasses, PG-60Waterleg and doorframe ring, PFT-5Waterleg flanges, joined by welding, PFT-21, PWT-12Waterleg joints, formed by welding, Fig. PFT-21Water level indicators, PG-60Waterside fusible plugs, A-20

rings, material of, PFT-5Welded connections of superheater tubes, PW-41Welded joints, between staybolted box header sheets, PWT-12

electric resistance butt, PW-27inspection during fabrication, PW-46



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2010 SECTION I

longitudinal and circumferential, PW-35postweld heat treatment, PW-39preheating, PW-38radiographic testing, PW-51repair of defects in, PW-40unreinforced, holes in, PW-14

Welded pipe connections, PW-41Welded piping connecting to boiler outlets, PW-35Welded stays, PW-19Welding, Part PW

materials acceptable for, PW-5of nozzles, PW-16of stays, fusion, PW-19, PFT-24operator, qualification of, PW-28preparation of base metal for, PW-29

270

processes, acceptable, PW-27procedure, qualification of, PW-28terms, definitions of, PW-1, PW-27test requirements, PW-46 to PW-54

Wet-bottom boilers, height from floor line, PFT-46Working pressure, for braced and stayed surfaces, PG-46

for steel fittings, PG-42for tubes, of firetube boilers, PFT-12

of watertube boilers, PG-27maximum, PG-21, PG-27on flat surfaces, PG-46on shells, PG-21

Wrapper sheet of locomotive type boiler, PFT-23Wrought iron (see Iron)Wrought steel (see Steel)



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INTENTIONALLY LEFT BLANK



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The ASME Boiler and Pressure Vessel Code (BPVC) is “An International Historic Mechanical Engineering Landmark,” widely recognized as a model for codes and standards worldwide. Its development process remains open and transparent throughout, yielding “living documents” that have improved public safety and facilitated trade across global markets and jurisdictions for nearly a century.

ASME also provides BPVC users with integrated suites of related offerings: • referenced standards • training courses• related standards and guidelines • ASME press books and journals• conformity assessment programs • conferences and proceedings

You gain unrivalled insight direct from the BPVC source, along with the professional quality and real-world solutions you have come to expect from ASME.

For additional information and to order:Phone: 1.800.843.2763Email: [email protected]: go.asme.org/bpvc10

2010 ASME Boiler and Pressure Vessel CodeA N I N T E R N A T I O N A L C O D E

X00010Copyright ASME International Provided by IHS under license with ASME Licensee=Korea Power Engineering Co Inc ( KOPEC ) /3289500001


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